10-K

	UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549
	FORM	10-K
☒	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the fiscal year ended	December 31, 2019
	or
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE      SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ____________ to ____________

Registrant; State of Incorporation; Address; Telephone Number;

Commission File Number; and I.R.S. Employer Identification No.

EVERSOURCE ENERGY

(a Massachusetts voluntary association)

300 Cadwell Drive, Springfield, Massachusetts 01104

Telephone: (800) 286-5000

Commission File Number: 1-5324

I.R.S. Employer Identification No. 04-2147929

THE CONNECTICUT LIGHT AND POWER COMPANY

(a Connecticut corporation)

107 Selden Street, Berlin, Connecticut 06037-1616

Telephone: (800) 286-5000

Commission File Number: 0-00404

I.R.S. Employer Identification No. 06-0303850

NSTAR ELECTRIC COMPANY

(a Massachusetts corporation)

800 Boylston Street, Boston, Massachusetts 02199

Telephone: (800) 286-5000

Commission File Number: 1-02301

I.R.S. Employer Identification No. 04-1278810

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE

(a New Hampshire corporation)

Energy Park

780 North Commercial Street, Manchester, New Hampshire 03101-1134

Telephone: (800) 286-5000

Commission File Number: 1-6392

I.R.S. Employer Identification No. 02-0181050

Securities registered pursuant to Section 12(b) of the Act:
Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Shares, $5.00 par value per share	ES	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act:

Registrant	Title of Class
The Connecticut Light and Power Company	Preferred Stock, par value $50.00 per share, issuable in series, of which the following series are outstanding:
		$1.90 $2.00 $2.04 $2.20 3.90% $2.06 $2.09 4.50% 4.96% 4.50% 5.28% $3.24 6.56%	Series  Series Series Series Series Series E Series F Series Series Series Series Series G Series	of 1947 of 1947 of 1949 of 1949 of 1949 of 1954 of 1955 of 1956 of 1958 of 1963 of 1967 of 1968 of 1968
NSTAR Electric Company	Preferred Stock, par value $100.00 per share, issuable in series, of which the following series are outstanding:
		4.25% 4.78%	Series Series	of 1956 of 1958

NSTAR Electric Company and Public Service Company of New Hampshire each meet the conditions set forth in General Instruction I(1)(a) and (b) of Form 10-K, and each is therefore filing this Form 10-K with the reduced disclosure format specified in General Instruction I(2) of Form 10‑K.  

Indicate by check mark if the registrants are well-known seasoned issuers, as defined in Rule 405 of the Securities Act.

Yes	No
☒	☐

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

Yes	No
☐	☒

Indicate by check mark whether the registrants (1) have 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 registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

Yes	No
☒	☐

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

Yes	No
☒	☐

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

Eversource Energy	Large accelerated filer	☒	Accelerated filer	☐	Non-accelerated filer	☐	Smaller reporting company	☐	Emerging growth company	☐
The Connecticut Light and Power Company	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
NSTAR Electric Company	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Public Service Company of New Hampshire	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐

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

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Act):

	Yes	No
Eversource Energy	☐	☒
The Connecticut Light and Power Company	☐	☒
NSTAR Electric Company	☐	☒
Public Service Company of New Hampshire	☐	☒

The aggregate market value of Eversource Energy's Common Shares, $5.00 par value, held by non-affiliates, computed by reference to the price at which the common equity was last sold, or the average bid and asked price of such common equity, as of the last business day of Eversource Energy's most recently completed second fiscal quarter (June 30, 2019) was $24,486,439,602 based on a closing market price of $75.76 per share for the 323,210,660 common shares outstanding held by non-affiliates on June 30, 2019.  

Indicate the number of shares outstanding of each of the registrant's classes of common stock, as of the latest practicable date:

Company - Class of Stock	Outstanding as of January 31, 2020
Eversource Energy Common Shares, $5.00 par value	329,952,663	shares
The Connecticut Light and Power Company Common Stock, $10.00 par value	6,035,205	shares
NSTAR Electric Company Common Stock, $1.00 par value	200	shares
Public Service Company of New Hampshire Common Stock, $1.00 par value	301	shares

Eversource Energy holds all of the 6,035,205 shares, 200 shares and 301 shares of the outstanding common stock of The Connecticut Light and Power Company, NSTAR Electric Company and Public Service Company of New Hampshire, respectively.

Eversource Energy, The Connecticut Light and Power Company, NSTAR Electric Company and Public Service Company of New Hampshire each separately file this combined Form 10-K.  Information contained herein relating to any individual registrant is filed by such registrant on its own behalf.  Each registrant makes no representation as to information relating to the other registrants.

GLOSSARY OF TERMS

The following is a glossary of abbreviations and acronyms that are found in this report:

Current or former Eversource Energy companies, segments or investments:
Eversource, ES or the Company	Eversource Energy and subsidiaries
Eversource parent or ES parent	Eversource Energy, a public utility holding company
ES parent and other companies	ES parent and other companies are comprised of Eversource parent, Eversource Service, Eversource Water Ventures, Inc. (parent company of Aquarion), and other subsidiaries, which primarily includes our unregulated businesses, HWP Company, The Rocky River Realty Company (a real estate subsidiary), the consolidated operations of CYAPC and YAEC, and Eversource parent's equity ownership interests that are not consolidated
CL&P	The Connecticut Light and Power Company
NSTAR Electric	NSTAR Electric Company
PSNH	Public Service Company of New Hampshire
PSNH Funding	PSNH Funding LLC 3, a bankruptcy remote, special purpose, wholly-owned subsidiary of PSNH
NSTAR Gas	NSTAR Gas Company
Yankee Gas	Yankee Gas Services Company
Aquarion	Eversource Aquarion Holdings, Inc. and its subsidiaries
NPT	Northern Pass Transmission LLC
Northern Pass	The HVDC and associated alternating-current transmission line project from Canada into New Hampshire
Eversource Service	Eversource Energy Service Company
Bay State Wind	Bay State Wind LLC, an offshore wind business being developed jointly by Eversource and Denmark-based Ørsted, which holds the Sunrise Wind project
North East Offshore	North East Offshore, LLC, an offshore wind business holding company being developed jointly by Eversource and Denmark-based Ørsted, which holds the Revolution Wind and South Fork Wind projects
CYAPC	Connecticut Yankee Atomic Power Company
MYAPC	Maine Yankee Atomic Power Company
YAEC	Yankee Atomic Electric Company
Yankee Companies	CYAPC, YAEC and MYAPC
Regulated companies	The Eversource regulated companies are comprised of the electric distribution and transmission businesses of CL&P, NSTAR Electric and PSNH, the natural gas distribution businesses of Yankee Gas and NSTAR Gas, NPT, Aquarion, and the solar power facilities of NSTAR Electric
Regulators:
DEEP	Connecticut Department of Energy and Environmental Protection
DOE	U.S. Department of Energy
DOER	Massachusetts Department of Energy Resources
DPU	Massachusetts Department of Public Utilities
EPA	U.S. Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
ISO-NE	ISO New England, Inc., the New England Independent System Operator
MA DEP	Massachusetts Department of Environmental Protection
NHPUC	New Hampshire Public Utilities Commission
PURA	Connecticut Public Utilities Regulatory Authority
SEC	U.S. Securities and Exchange Commission
SJC	Supreme Judicial Court of Massachusetts
Other Terms and Abbreviations:
ADIT	Accumulated Deferred Income Taxes
AFUDC	Allowance For Funds Used During Construction
AOCI	Accumulated Other Comprehensive Income
ARO	Asset Retirement Obligation
Bcf	Billion cubic feet
C&LM	Conservation and Load Management
CfD	Contract for Differences
CTA	Competitive Transition Assessment
CWIP	Construction Work in Progress
EDC	Electric distribution company
EDIT	Excess Deferred Income Taxes
EPS	Earnings Per Share
ERISA	Employee Retirement Income Security Act of 1974

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ESOP	Employee Stock Ownership Plan
Eversource 2018 Form 10-K	The Eversource Energy and Subsidiaries 2018 combined Annual Report on Form 10-K as filed with the SEC
Fitch	Fitch Ratings
FMCC	Federally Mandated Congestion Charge
FTR	Financial Transmission Rights
GAAP	Accounting principles generally accepted in the United States of America
GSC	Generation Service Charge
GSRP	Greater Springfield Reliability Project
GWh	Gigawatt-Hours
HQ	Hydro-Québec, a corporation wholly-owned by the Québec government, including its divisions that produce, transmit and distribute electricity in Québec, Canada
HVDC	High-voltage direct current
Hydro Renewable Energy	Hydro Renewable Energy, Inc., a wholly-owned subsidiary of Hydro-Québec
IPP	Independent Power Producers
ISO-NE Tariff	ISO-NE FERC Transmission, Markets and Services Tariff
kV	Kilovolt
kVa	Kilovolt-ampere
kW	Kilowatt (equal to one thousand watts)
LBR	Lost Base Revenue
LNG	Liquefied natural gas
LRS	Supplier of last resort service
MG	Million gallons
MGP	Manufactured Gas Plant
MMBtu	One million British thermal units
MMcf	Million cubic feet
Moody's	Moody's Investors Services, Inc.
MW	Megawatt
MWh	Megawatt-Hours
NEEWS	New England East-West Solution
NETOs	New England Transmission Owners (including Eversource, National Grid and Avangrid)
OCI	Other Comprehensive Income/(Loss)
PAM	Pension and PBOP Rate Adjustment Mechanism
PBOP	Postretirement Benefits Other Than Pension
PBOP Plan	Postretirement Benefits Other Than Pension Plan
Pension Plan	Single uniform noncontributory defined benefit retirement plan
PPA	Power purchase agreement
RECs	Renewable Energy Certificates
Regulatory ROE	The average cost of capital method for calculating the return on equity related to the distribution business segment excluding the wholesale transmission segment
ROE	Return on Equity
RRBs	Rate Reduction Bonds or Rate Reduction Certificates
RSUs	Restricted share units
S&P	Standard & Poor's Financial Services LLC
SBC	Systems Benefits Charge
SCRC	Stranded Cost Recovery Charge
SERP	Supplemental Executive Retirement Plans and non-qualified defined benefit retirement plans
SS	Standard service
TCAM	Transmission Cost Adjustment Mechanism
TSA	Transmission Service Agreement
UI	The United Illuminating Company
VIE	Variable Interest Entity

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EVERSOURCE ENERGY AND SUBSIDIARIES

THE CONNECTICUT LIGHT AND POWER COMPANY

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

2019 FORM 10-K ANNUAL REPORT

TABLE OF CONTENTS

		Page
PART I
Item 1.	Business	2
Item 1A.	Risk Factors	14
Item 1B.	Unresolved Staff Comments	18
Item 2.	Properties	19
Item 3.	Legal Proceedings	21
Item 4.	Mine Safety Disclosures	22
PART II
Item 5.	Market for the Registrants’ Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	22
Item 6.	Selected Consolidated Financial Data	23
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
Item 7A.	Quantitative and Qualitative Disclosures about Market Risk	48
Item 8.	Financial Statements and Supplementary Data	49
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	123
Item 9A.	Controls and Procedures	123
Item 9B.	Other Information	123
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	124
Item 11.	Executive Compensation	125
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	154
Item 13.	Certain Relationships and Related Transactions, and Director Independence	155
Item 14.	Principal Accountant Fees and Services	156
PART IV
Item 15.	Exhibits and Financial Statement Schedules	158
Item 16.	Form 10-K Summary	158
Signatures		E-9

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EVERSOURCE ENERGY AND SUBSIDIARIES

THE CONNECTICUT LIGHT AND POWER COMPANY

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

SAFE HARBOR STATEMENT UNDER THE PRIVATE SECURITIES

LITIGATION REFORM ACT OF 1995

References in this Annual Report on Form 10-K to "Eversource," the "Company," "we," "our," and "us" refer to Eversource Energy and its consolidated subsidiaries. CL&P, NSTAR Electric, and PSNH are each doing business as Eversource Energy.  

From time to time, we make statements concerning our expectations, beliefs, plans, objectives, goals, strategies, assumptions of future events, future financial performance or growth and other statements that are not historical facts.  These statements are "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995.  You can generally identify our forward-looking statements through the use of words or phrases such as "estimate," "expect," "anticipate," "intend," "plan," "project," "believe," "forecast," "should," "could," and other similar expressions.  Forward-looking statements are based on the current expectations, estimates, assumptions or projections of management and are not guarantees of future performance.  These expectations, estimates, assumptions or projections may vary materially from actual results.  Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, the following important factors that could cause our actual results to differ materially from those contained in our forward-looking statements, including, but not limited to:

• cyberattacks or breaches, including those resulting in the compromise of the confidentiality of our proprietary information and the personal information of our customers,

• ability or inability to commence and complete our major strategic development projects and opportunities,

• acts of war or terrorism, physical attacks or grid disturbances that may damage and disrupt our electric transmission and electric, natural gas, and water distribution systems,

• actions or inaction of local, state and federal regulatory, public policy and taxing bodies,

• substandard performance of third-party suppliers and service providers,

• fluctuations in weather patterns, including extreme weather due to climate change,

• changes in business conditions, which could include disruptive technology or development of alternative energy sources related to our current or future business model,

• contamination of, or disruption in, our water supplies,

• changes in economic conditions, including impact on interest rates, tax policies, and customer demand and payment ability,

• changes in levels or timing of capital expenditures,

• disruptions in the capital markets or other events that make our access to necessary capital more difficult or costly,

• changes in laws, regulations or regulatory policy, including compliance with environmental laws and regulations,

• changes in accounting standards and financial reporting regulations,

• actions of rating agencies, and

• other presently unknown or unforeseen factors.  

Other risk factors are detailed in our reports filed with the SEC and updated as necessary, and we encourage you to consult such disclosures.

All such factors are difficult to predict and contain uncertainties that may materially affect our actual results, many of which are beyond our control.  You should not place undue reliance on the forward-looking statements, as each speaks only as of the date on which such statement is made, and, except as required by federal securities laws, we undertake no obligation to update any forward-looking statement or statements to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events.  New factors emerge from time to time and it is not possible for us to predict all of such factors, nor can we assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements. For more information, see Item 1A, Risk Factors, included in this combined Annual Report on Form 10-K. This Annual Report on Form 10-K also describes material contingencies and critical accounting policies in the accompanying Management's Discussion and Analysis of Financial Condition and Results of Operations and Combined Notes to Financial Statements.  We encourage you to review these items.  

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EVERSOURCE ENERGY AND SUBSIDIARIES

THE CONNECTICUT LIGHT AND POWER COMPANY

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

PART I

Item 1.    Business

Please refer to the Glossary of Terms for definitions of defined terms and abbreviations used in this combined Annual Report on Form 10-K.

Eversource Energy, headquartered in Boston, Massachusetts and Hartford, Connecticut, is a public utility holding company subject to regulation by the FERC under the Public Utility Holding Company Act of 2005. We are engaged primarily in the energy delivery business through the following wholly-owned utility subsidiaries:

• The Connecticut Light and Power Company (CL&P), a regulated electric utility that serves residential, commercial and industrial customers in parts of Connecticut;

• NSTAR Electric Company (NSTAR Electric), a regulated electric utility that serves residential, commercial and industrial customers in parts of eastern and western Massachusetts and owns solar power facilities;

• Public Service Company of New Hampshire (PSNH), a regulated electric utility that serves residential, commercial and industrial customers in parts of New Hampshire;

• NSTAR Gas Company (NSTAR Gas), a regulated natural gas utility that serves residential, commercial and industrial customers in parts of Massachusetts;

• Yankee Gas Services Company (Yankee Gas), a regulated natural gas utility that serves residential, commercial and industrial customers in parts of Connecticut; and

• Eversource Aquarion Holdings, Inc. (Aquarion), a utility holding company that owns three separate regulated water utility subsidiaries and collectively serves residential, commercial, industrial, and municipal and fire protection customers in parts of Connecticut, Massachusetts and New Hampshire.

CL&P, NSTAR Electric and PSNH also serve New England customers through Eversource Energy's electric transmission business. Along with NSTAR Gas and Yankee Gas, each is doing business as Eversource Energy in its respective service territory.

Eversource Energy, CL&P, NSTAR Electric and PSNH each report their financial results separately. We also include information in this report on a segment basis for Eversource Energy. Eversource Energy has four reportable segments: electric distribution, electric transmission, natural gas distribution and water distribution. These segments represent substantially all of Eversource Energy's total consolidated revenues. CL&P, NSTAR Electric and PSNH do not report separate business segments.

ELECTRIC DISTRIBUTION SEGMENT

Eversource Energy's electric distribution segment consists of the distribution businesses of CL&P, NSTAR Electric and PSNH, which are engaged in the distribution of electricity to retail customers in Connecticut, Massachusetts and New Hampshire, respectively, and the solar power facilities of NSTAR Electric, and the generation facilities of PSNH before such facilities were sold in January and August 2018.

ELECTRIC DISTRIBUTION – CONNECTICUT – THE CONNECTICUT LIGHT AND POWER COMPANY

CL&P's distribution business consists primarily of the purchase, delivery and sale of electricity to its residential, commercial and industrial customers. As of December 31, 2019, CL&P furnished retail franchise electric service to approximately 1.26 million customers in 149 cities and towns in Connecticut, covering an area of approximately 4,400 square miles. CL&P does not own any electric generation facilities.

Rates

CL&P is subject to regulation by the PURA, which, among other things, has jurisdiction over rates, certain dispositions of property and plant, mergers and consolidations, issuances of long-term securities, standards of service and construction and operation of facilities.  CL&P's present general rate structure consists of various rate and service classifications covering residential, commercial and industrial services.  CL&P's retail rates include a delivery service component, which includes distribution, transmission, conservation, renewable energy programs and other charges that are assessed on all customers.

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Under Connecticut law, all of CL&P's customers are entitled to choose their energy suppliers, while CL&P remains their electric distribution company.  For those customers who do not choose a competitive energy supplier, under SS rates for customers with less than 500 kilowatts of demand (residential customers and small and medium commercial and industrial customers), and LRS rates for customers with 500 kilowatts or more of demand (larger commercial and industrial customers), CL&P purchases power under standard offer contracts and passes the cost of the purchased power to customers through a combined charge on customers' bills.

The rates established by the PURA for CL&P are comprised of the following:

• An electric GSC, which recovers energy-related costs incurred as a result of providing electric generation service supply to all customers that have not migrated to competitive energy suppliers.  The GSC is adjusted periodically and reconciled annually in accordance with the policies and procedures of the PURA, with any differences refunded to, or recovered from, customers.

• A revenue decoupling adjustment that reconciles annual base distribution rate recovery amounts recovered from customers to the pre-established level of baseline distribution delivery service revenue requirement approved by the PURA of $1.099 billion effective May 1, 2018, $1.127 billion effective May 1, 2019, and $1.158 billion effective May 1, 2020. These pre-established levels of baseline distribution delivery service revenue requirement are also subject to adjustment at each of these dates in accordance with provisions of the April 2018 rate case settlement agreement.

• A distribution charge, which includes a fixed customer charge and a demand and/or energy charge to collect the costs of building and expanding the infrastructure to deliver electricity to customers, as well as ongoing operating costs to maintain the infrastructure.  

• An Electric System Improvements (ESI) charge, which collects the costs of building and expanding the infrastructure to deliver electricity to customers above the level recovered through the distribution charge. The ESI also recovers costs associated with CL&P’s system resiliency program. The ESI is adjusted periodically and reconciled annually in accordance with the policies and procedures of the PURA, with any differences refunded to, or recovered from, customers.

• An FMCC, which recovers any costs imposed by the FERC as part of the New England Standard Market Design, including locational marginal pricing, locational installed capacity payments, and any costs approved by the PURA to reduce these charges.  The FMCC has both a bypassable component and a non-bypassable component, and is adjusted periodically and reconciled annually in accordance with the policies and procedures of the PURA, with any differences refunded to, or recovered from, customers.

• A transmission charge that recovers the cost of transporting electricity over high-voltage lines from generating plants to substations, including costs allocated by ISO-NE to maintain the wholesale electric market. The transmission charge is adjusted periodically and reconciled annually to actual costs incurred, and reviewed by the PURA, with any difference refunded to, or recovered from, customers.

• A CTA charge, assessed to recover stranded costs associated with electric industry restructuring such as various IPP contracts.  The CTA is reconciled annually to actual costs incurred and reviewed by the PURA, with any difference refunded to, or recovered from, customers.

• An SBC, established to fund expenses associated with various hardship and low-income programs. The SBC is reconciled annually to actual costs incurred and reviewed by the PURA, with any difference refunded to, or recovered from, customers.  

• A Renewable Energy Investment Charge, which is used to promote investment in renewable energy sources.  Amounts collected by this charge are deposited into the Connecticut Clean Energy Fund and administered by the Connecticut Green Bank.  

• A conservation charge, comprised of both a statutory rate and Conservation Adjustment Mechanism (CAM) established to implement cost-effective energy conservation programs and market transformation initiatives. The conservation charge is reconciled annually to actual costs incurred, and reviewed by the PURA, with any difference refunded to, or recovered from, customers through an approved adjustment to the following year’s energy conservation spending plan budget.

As required by regulation, CL&P has entered into long-term contracts for the purchase of (i) products from renewable energy facilities, which may include energy, renewable energy certificates, or capacity, (ii) capacity-related contracts with generation facilities, and (iii) contracts for peaking capacity.  Some of these contracts are subject to sharing agreements with UI, whereby CL&P is responsible for 80 percent and UI for 20 percent of the net costs or benefits.  CL&P's portion of the costs and benefits of these contracts will be paid by, or refunded to, CL&P's customers.

Distribution Rate Case: CL&P's distribution rates were established in an April 2018 PURA-approved rate case settlement agreement with rates effective May 1, 2018.

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Sources and Availability of Electric Power Supply

As noted above, CL&P does not own any generation assets and purchases energy supply to serve its SS and LRS loads from a variety of competitive sources through requests for proposals. During 2019, CL&P supplied approximately 46 percent of its customer load at SS or LRS rates while the other 54 percent of its customer load had migrated to competitive energy suppliers.  In terms of the total number of CL&P customers, this equates to 25 percent being on competitive supply, while 75 percent remain with SS or LRS. Because this customer migration is only for energy supply service, it has no impact on CL&P's electric distribution business or its operating income.

CL&P periodically enters into full requirements contracts for SS loads for periods of up to one year. CL&P typically enters into full requirements contracts for LRS loads every three months. Currently, CL&P has full requirements contracts in place for 100 percent of its SS loads for the first half of 2020. For the second half of 2020, CL&P has 70 percent of its SS load under full requirements contracts and intends to purchase an additional 30 percent of full requirements. None of the SS load for 2021 has been procured. CL&P has full requirements contracts in place for its LRS loads through June 2020 and intends to purchase 100 percent of full requirements for the remainder of 2020.

ELECTRIC DISTRIBUTION – MASSACHUSETTS – NSTAR ELECTRIC COMPANY

NSTAR Electric's distribution business consists primarily of the purchase, delivery and sale of electricity to its residential, commercial and industrial customers. As of December 31, 2019, NSTAR Electric furnished retail franchise electric service to approximately 1.44 million customers in Boston and 139 cities and towns in eastern and western Massachusetts, including Cape Cod, Martha's Vineyard and the greater Springfield metropolitan area, covering an aggregate area of approximately 3,200 square miles.

NSTAR Electric does not own any generating facilities that are used to supply customers and purchases its energy requirements from competitive energy suppliers.

NSTAR Electric installed and completed nineteen new solar power facilities for a total of 62 MW by the end of 2019.  These solar sites are in addition to the 8 MW of solar power facilities constructed between 2010 and 2014.  NSTAR Electric now owns, operates and maintains a total of 70 MW of solar power facilities on twenty-two sites in Massachusetts.  NSTAR Electric will sell energy from the new facilities into the ISO-NE market, with proceeds credited to customers.

Rates

NSTAR Electric is subject to regulation by the DPU, which, among other things, has jurisdiction over rates, certain dispositions of property and plant, mergers and consolidations, issuances of long-term securities, acquisition of securities, standards of service and construction and operation of facilities.  The present general rate structure for NSTAR Electric consists of various rate and service classifications covering residential, commercial and industrial services.

Under Massachusetts law, all customers of NSTAR Electric are entitled to choose their energy suppliers, while NSTAR Electric remains their electric distribution company.  NSTAR Electric purchases power from competitive suppliers on behalf of, and passes the related cost through to, its customers who do not choose a competitive energy supplier (basic service). Electric distribution companies in Massachusetts are required to obtain and resell power to retail customers through basic service for those who choose not to buy energy from a competitive energy supplier.  Most of the residential customers of NSTAR Electric have continued to buy their power from NSTAR Electric at basic service rates.  Most commercial and industrial customers have switched to a competitive energy supplier.

The Cape Light Compact, an inter-governmental organization consisting of the 21 towns and two counties on Cape Cod and Martha's Vineyard, serves 200,000 customers through the delivery of energy efficiency programs, consumer advocacy, competitive electricity supply and green power options.  NSTAR Electric continues to provide electric service to these customers including the delivery of power, maintenance of infrastructure, capital investment, meter reading, billing, and customer service.

The rates established by the DPU for NSTAR Electric are comprised of the following:

• A basic service charge that represents the collection of energy costs incurred as a result of providing electric generation service supply to all customers that have not migrated to competitive energy suppliers, including costs related to charge-offs of uncollectible energy costs from customers.  Basic service rates are reset every six months (every three months for large commercial and industrial customers). Additionally, the DPU has authorized NSTAR Electric to recover the cost of its NSTAR Green wind contracts through the basic service charge. Basic service costs are reconciled annually, with any differences refunded to, or recovered from, customers.

• A distribution charge, which includes a fixed customer charge and a demand and/or energy charge to collect the costs of building and expanding the distribution infrastructure to deliver electricity to its destination, as well as ongoing operating costs.

• A revenue decoupling adjustment that reconciles annual base distribution rate recovery amounts recovered from customers to the pre-established level of baseline distribution delivery service revenue requirement approved by the DPU of $956 million on an annualized basis for 2018 and $988 million for 2019. Annual base distribution amounts are adjusted for inflation and filed for approval by the DPU on an annual basis, until the next rate case.

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• A transmission charge that recovers the cost of transporting electricity over high-voltage lines from generating plants to substations, including costs allocated by ISO-NE to maintain the wholesale electric market. The transmission charge is reconciled annually to actual costs incurred and reviewed by the DPU, with any difference refunded to, or recovered from, customers.

• A transition charge that represents costs to be collected primarily from previously held investments in generating plants, costs related to existing above-market power contracts, and contract costs related to long-term power contract buy-outs. The transition charge is reconciled annually to actual costs incurred and reviewed by the DPU, with any difference refunded to, or recovered from, customers.

• A renewable energy charge that represents a legislatively-mandated charge to support the Massachusetts Renewable Energy Trust Fund.

• An energy efficiency charge that represents a legislatively-mandated charge to collect costs for energy efficiency programs. The energy efficiency charge is reconciled annually to actual costs incurred and reviewed by the DPU, with any difference refunded to, or recovered from, customers.

• Reconciling adjustment charges that recover certain DPU-approved costs, including pension and PBOP benefits, low income customer discounts, credits issued to net-metering facilities installed by customers, payments to solar facilities qualified under the state solar renewable energy target program, attorney general consultant expenses, long-term renewable contracts, company-owned solar facilities, vegetation management costs, credits related to the Tax Cuts and Jobs Act of 2017, grid modernization costs, and storm restoration. These charges are reconciled annually to actual costs incurred and reviewed by the DPU, with any difference refunded to, or recovered from, customers.

NSTAR Electric has signed long-term commitments for the purchase of energy from renewable energy facilities.

Distribution Rate Case: NSTAR Electric's distribution rates were established in a 2017 DPU-approved rate case with rates effective February 1, 2018.

Service Quality Metrics: NSTAR Electric is subject to service quality (SQ) metrics that measure safety, reliability and customer service, and could be required to pay to customers a SQ charge of up to 2.5 percent of annual transmission and distribution revenues for failing to meet such metrics. NSTAR Electric will not be required to pay a SQ charge for its 2019 performance as the company achieved results at or above target for all of its SQ metrics in 2019.

Sources and Availability of Electric Power Supply

As noted above, NSTAR Electric does not own any generation assets (other than 70 MW of solar power facilities that produce energy that is sold into the ISO-NE market) and purchases its energy requirements from a variety of competitive sources through requests for proposals issued periodically, consistent with DPU regulations. NSTAR Electric enters into supply contracts for basic service for approximately 45 percent of its residential and small commercial and industrial (C&I) customers twice per year for twelve-month terms. NSTAR Electric enters into supply contracts for basic service for 18 percent of large C&I customers every three months.

During 2019, NSTAR Electric supplied approximately 44 percent of its residential customer load, 31 percent of its small C&I customer load, and 8 percent of its large C&I customer load at basic service rates. The remainder of its customer load was distributed between municipal aggregation and competitive supply. Because customer migration is limited to energy supply service, it has no impact on the delivery business or operating income of NSTAR Electric.

ELECTRIC DISTRIBUTION – NEW HAMPSHIRE – PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE

PSNH's distribution business consists primarily of the purchase, delivery and sale of electricity to its residential, commercial and industrial customers. As of December 31, 2019, PSNH furnished retail franchise electric service to approximately 523,000 retail customers in 211 cities and towns in New Hampshire, covering an area of approximately 5,630 square miles.

On January 10, 2018, PSNH completed the sale of its thermal generation assets pursuant to a 2017 purchase and sale agreement. The thermal generation facilities included approximately 1,100 MW of coal, natural gas, biomass and oil-fired electricity generation facilities. On August 26, 2018, PSNH completed the sale of its hydroelectric generation assets pursuant to a separate 2017 purchase and sale agreement. For further information, see "Generation Divestiture" below. As of December 31, 2019, PSNH does not own any electric generation facilities.

Rates

PSNH is subject to regulation by the NHPUC, which, among other things, has jurisdiction over rates, certain dispositions of property and plant, mergers and consolidations, issuances of securities, standards of service and construction and operation of facilities.

Under New Hampshire law, all of PSNH's customers are entitled to choose competitive energy suppliers. During 2019, approximately 23 percent of all of PSNH's customers (approximately 56 percent of load) were taking service from competitive energy suppliers.

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The rates established by the NHPUC for PSNH are comprised of the following:

• A default energy service charge recovers energy-related costs incurred as a result of providing electric generation service supply to all customers that have not migrated to competitive energy suppliers. Through March 31, 2018, the default energy service charge recovered the costs of PSNH's generation, as well as purchased power, and included an allowed ROE of 9.81 percent. Effective April 1, 2018, as a result of the completion of the divestiture of its non-hydro generation assets, PSNH purchased power for retail customers who had not chosen a competitive supplier through a periodic market solicitation with the rate set to recover the cost of that power, statutorily mandated renewable portfolio standard costs and the continued cost associated with the ownership of the Hydro generation units until the completion of the divestiture of the hydro units in August 2018. Effective September 1, 2018, any remaining costs from ownership of generation are recovered as part of the SCRC described below.

• A distribution charge, which includes kilowatt-hour and/or demand-based charges to recover costs related to the maintenance and operation of PSNH's infrastructure to deliver power to its destination, as well as power restoration and service costs.  It also includes a customer charge to collect the cost of providing service to a customer; such as the installation, maintenance, reading and replacement of meters and maintaining accounts and records.  

• A transmission charge that recovers the cost of transporting electricity over high-voltage lines from generating plants to substations, including costs allocated by ISO-NE to maintain the wholesale electric market.

• An SCRC, which allows PSNH to recover its stranded costs, including above-market expenses incurred under mandated power purchase obligations, other long-term investments and obligations, and the remaining costs associated with the 2018 sales of its generation facilities.

• An SBC, which funds energy efficiency programs for all customers, as well as assistance programs for residential customers within certain income guidelines.

PSNH has signed long-term commitments for the purchase of energy from renewable energy facilities.

The default energy service charge and SCRC rates change semi-annually and the transmission and SBC rates change annually. These rates are reconciled annually in accordance with the policies and procedures of the NHPUC, with any differences refunded to, or recovered from, customers.

Distribution Rate Case: PSNH distribution rates were last established in a settlement approved by the NHPUC in 2010.  Prior to the expiration of that settlement on June 30, 2015, the NHPUC approved the continuation of those rates, and increased funding via rates, of PSNH's reliability enhancement program.

On April 26, 2019, PSNH filed an application with the NHPUC for approval of a temporary annual base distribution rate increase of approximately $33 million, effective July 1, 2019. On June 27, 2019, the NHPUC approved a settlement agreement that was reached by PSNH, the NHPUC Staff, the Office of the Consumer Advocate, and another settling party, to implement a temporary annual base distribution rate increase of $28.3 million. Although new rates were implemented on August 1, 2019 to customers, the provisions of the temporary base distribution rate increase were effective July 1, 2019. The settlement agreement also permits PSNH to recover approximately $68.5 million in unrecovered storm costs over a five-year period beginning August 1, 2019, with debt carrying charges, which is included in the temporary rate increase.

On May 28, 2019, PSNH filed an application with the NHPUC for a permanent increase in base distribution rates of approximately $70 million, effective July 1, 2020, which includes the temporary rate increase request.  The temporary rates are subject to reconciliation based on the outcome of the permanent rate case now before the NHPUC. The NHPUC is permitted up to twelve months to adjudicate the permanent rate application from the date of filing. A decision by the NHPUC is expected in the second quarter of 2020.

Generation Divestiture

In June 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement, pursuant to which PSNH agreed to divest its generation assets, subject to NHPUC approval.  The NHPUC approved this agreement as well as the final divestiture plan and auction process in 2016. On October 11, 2017, PSNH entered into two Purchase and Sale Agreements with private investors, one to sell its thermal generation assets at a purchase price of $175 million, subject to adjustment, (the “Thermal Agreement”) and a second to sell its hydroelectric generation assets at a purchase price of $83 million, subject to adjustment (the “Hydro Agreement”). The NHPUC approved these agreements in late November 2017.

On January 10, 2018, PSNH completed the sale of its thermal generation assets pursuant to the Thermal Agreement. In accordance with the Thermal Agreement, the original purchase price of $175 million was adjusted to reflect working capital adjustments, closing date adjustments and proration of taxes and fees prior to closing, totaling $40.9 million. In the second quarter of 2018, the purchase price was further adjusted by $17.3 million relating to the valuation of certain allowances. As a result of these adjustments, net proceeds from the sale of the thermal assets totaled $116.8 million.

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On July 16, 2018, FERC issued its order approving the transfer of PSNH's six hydroelectric licenses to private investors. On August 26, 2018, PSNH completed the sale of its hydroelectric generation assets pursuant to the Hydro Agreement. In accordance with the Hydro Agreement, the original purchase price of $83 million was adjusted to reflect contractual adjustments totaling $5.8 million, resulting in net proceeds of $77.2 million. The difference between the carrying value of the hydroelectric generation assets and the sale proceeds resulted in a gain of $17.3 million. An estimated gain from the sale of these assets was included as an offset to the total remaining costs associated with the sale of generation assets that were securitized on May 8, 2018.

On May 8, 2018, PSNH Funding issued $635.7 million of securitized RRBs pursuant to a finance order issued by the NHPUC on January 30, 2018 to recover remaining costs resulting from the divestiture of PSNH’s generation assets, which included the deferred costs resulting from the sale of the thermal generation assets. These RRBs are secured by a non-bypassable charge recoverable from PSNH customers. PSNH recorded regulatory assets and other deferred costs in connection with the generation asset divestiture and the securitization of remaining costs, which are probable of recovery through collection of the non-bypassable charge.

On November 27, 2019, PSNH filed a motion for the commencement of audit of divestiture-related costs. PSNH’s actual balance of costs eligible for recovery as divestiture-related costs is $654.0 million, which is above the $635.7 million amount securitized in May 2018. PSNH proposed to recover this balance through the SCRC tracker mechanism and believes the amount deferred is probable of recovery.

Sources and Availability of Electric Power Supply

PSNH does not own any generation assets and purchases energy supply from a variety of competitive suppliers for its energy service customers through requests for proposals issued twice per year, for six-month terms, for approximately 78 percent of its residential and small C&I customers and for 14 percent of its large C&I customers.

During 2019, PSNH supplied approximately 43 percent of its customer load at default energy service rates while the other 57 percent of its customer load had migrated to competitive energy suppliers.  Because this customer migration is only for energy supply service, it has no impact on PSNH’s electric distribution business or its operating income.

ELECTRIC TRANSMISSION SEGMENT

Each of CL&P, NSTAR Electric and PSNH owns and maintains transmission facilities that are part of an interstate power transmission grid over which electricity is transmitted throughout New England.  Each of CL&P, NSTAR Electric and PSNH, and most other New England utilities, are parties to a series of agreements that provide for coordinated planning and operation of the region's transmission facilities and the rules by which they acquire transmission services.  Under these arrangements, ISO-NE, a non-profit corporation whose board of directors and staff are independent of all market participants, serves as the regional transmission organization of the New England transmission system.  

Wholesale Transmission Rates

Wholesale transmission revenues are recovered through FERC-approved formula rates.  Annual transmission revenue requirements include recovery of transmission costs and include a return on equity applied to transmission rate base. Transmission revenues are collected from New England customers, including distribution customers of CL&P, NSTAR Electric and PSNH.  The transmission rates provide for an annual true-up of estimated to actual costs.  The financial impacts of differences between actual and estimated costs are deferred for future recovery from, or refund to, transmission customers.

FERC ROE Complaints

Four separate complaints were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively the "Complainants"). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive (incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

In response to appeals of the FERC decision in the first complaint filed by the NETOs and the Complainants, the U.S. Court of Appeals for the D.C. Circuit (the Court) issued a decision on April 14, 2017 vacating and remanding the FERC's decision. On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE.

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On November 21, 2019, FERC issued an order concerning the transmission ROEs for the Midcontinent ISO transmission owners (MISO). In that order, FERC adopted another new methodology for determining base ROEs for MISO, which differed significantly from the methodology and framework set forth in its October 16, 2018 FERC order on the NETOs’ ROE dockets. On December 23, 2019, the NETOs filed a Supplemental Paper Hearing Brief and a Motion to supplement the record in the NETO ROE dockets to respond to the new methodology proposed in the MISO order, as there is uncertainty to whether it may be applied to the NETOs’ cases. On January 21, 2020, the FERC issued an order granting rehearing for further consideration to give the FERC more time to act on the substantive issues of the MISO ROE proceedings. Further changes to the methodology by FERC are possible as a result of the arguments in both the MISO and NETO proceedings. Given the significant uncertainty relating to the October 2018 FERC order, the November 2019 FERC order to MISO, and the FERC's rehearing of the MISO order, the Company is unable to predict the potential effect of the MISO order on the NETO complaints or the outcome of the four complaints and concluded that there is no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods at this time. Further, the Company cannot reasonably estimate a range of gain or loss for any of the four complaint proceedings.

For further information, see "FERC Regulatory Matters - FERC ROE Complaints" in the accompanying Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.

Transmission Projects

During 2019, we were involved in the planning, development and construction of a series of electric transmission projects that will be built within the next two years and that will enhance system reliability and improve capacity. For more information on transmission projects, see "Business Development and Capital Expenditures – Electric Transmission Business" in the accompanying Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.

Northern Pass was Eversource's planned 1,090 MW HVDC transmission line that would have interconnected from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. As a result of a final decision received on July 19, 2019 from the New Hampshire Supreme Court, whereby the court denied Northern Pass’ appeal and affirmed the NHSEC’s denial of Northern Pass’ siting application on NPT, Eversource concluded that construction of NPT was no longer probable and that there was no constructive path forward for the project. Eversource terminated the project and permanently abandoned any further development.  As a result, substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired. For further information, see "Critical Accounting Policies - Impairment of Northern Pass Transmission" in the accompanying Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.

Transmission Rate Base

Transmission rate base under our FERC-approved tariff primarily consists of our investment in transmission net utility plant less accumulated deferred income taxes.

Under our FERC-approved tariff, and with the exception of transmission projects that received specific FERC approval to include CWIP in rate base, transmission projects generally enter rate base after they are placed in commercial operation. At the end of 2019, our estimated transmission rate base was approximately $7.3 billion, including approximately $3.3 billion at CL&P, $2.9 billion at NSTAR Electric, and $1.1 billion at PSNH.

NATURAL GAS DISTRIBUTION SEGMENT

NSTAR Gas distributes natural gas to approximately 300,000 customers in 51 communities in central and eastern Massachusetts covering 1,067 square miles, and Yankee Gas distributes natural gas to approximately 241,000 customers in 72 cities and towns in Connecticut covering 2,187 square miles. Total throughput (sales and transportation) in 2019 was approximately 73.5 Bcf for NSTAR Gas and 58.4 Bcf for Yankee Gas. Our natural gas businesses provide firm natural gas sales and transportation service to eligible retail customers who require a continuous natural gas supply throughout the year, such as residential customers who rely on natural gas for heating, hot water and cooking needs, as well as commercial and industrial customers that rely on natural gas for space heating, hot water, cooking and commercial and industrial applications.

A portion of the storage of natural gas supply for NSTAR Gas during the winter heating season is provided by Hopkinton LNG Corp., an indirect, wholly-owned subsidiary of Eversource Energy. NSTAR Gas has access to Hopkinton LNG Corp. facilities in Hopkinton, Massachusetts consisting of a LNG liquefaction and vaporization plant and three above-ground cryogenic storage tanks having an aggregate capacity of 3.0 Bcf of liquefied natural gas. NSTAR Gas also has access to Hopkinton LNG Corp. facilities in Acushnet, Massachusetts that include additional storage capacity of 0.5 Bcf. Total vaporization capacity of these facilities is 0.21 Bcf per day. Yankee Gas owns a 1.2 Bcf LNG facility in Waterbury, Connecticut, which also has the ability to liquefy and vaporize up to 0.1 Bcf per day. This facility is used primarily to assist Yankee Gas in meeting its supplier-of-last-resort obligations and also enables it to provide economic supply and make economic refill of natural gas, typically during periods of low demand.

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NSTAR Gas and Yankee Gas generate revenues primarily through the sale and/or transportation of natural gas.  While all NSTAR Gas customers have the ability to choose to transport natural gas, in the past year, transportation represented only approximately three percent of the total residential load, while transportation represented approximately 58 percent of the total commercial and industrial load. Retail natural gas service in Connecticut is partially unbundled: residential customers in Yankee Gas' service territory buy natural gas supply and delivery only from Yankee Gas while commercial and industrial customers may choose their natural gas suppliers. Firm transportation service is offered to customers who purchase natural gas from sources other than NSTAR Gas or Yankee Gas.  NSTAR Gas has the ability to offer interruptible transportation and interruptible natural gas sales service to high volume commercial and industrial customers. Yankee Gas offers interruptible transportation and interruptible natural gas sales service to commercial and industrial customers that have the ability to switch from natural gas to an alternate fuel on short notice. NSTAR Gas and Yankee Gas can interrupt service to these customers during peak demand periods or at any other time to maintain distribution system integrity.

Rates

NSTAR Gas and Yankee Gas are subject to regulation by the DPU and the PURA, respectively, which, among other things, have jurisdiction over rates, certain dispositions of property and plant, mergers and consolidations, issuances of long-term securities, standards of service and construction and operation of facilities.

Retail natural gas delivery and supply rates are established by the DPU and the PURA and are comprised of:

• A distribution charge consisting of a fixed customer charge and a demand and/or energy charge that collects the costs of building, maintaining, and expanding the natural gas infrastructure to deliver natural gas supply to its customers.  This also includes collection of ongoing operating costs.

• A seasonal cost of gas adjustment clause (CGAC) at NSTAR Gas that collects natural gas supply costs, pipeline and storage capacity costs, costs related to charge-offs of uncollected energy costs and working capital related costs.  The CGAC is reset semi-annually with any difference being recovered from, or refunded to, customers during the following corresponding season. In addition, NSTAR Gas files interim changes to its CGAC factor when the actual costs of natural gas supply vary from projections by more than five percent.

• A local distribution adjustment clause (LDAC) at NSTAR Gas that collects all energy efficiency and related program costs, environmental costs, pension and PBOP related costs, attorney general consultant costs, credits related to the Tax Cuts and Jobs Act of 2017, gas system enhancement program (GSEP) costs and costs associated with low income customers.  The LDAC is reset annually with any difference being recovered from, or refunded to, customers during the following period and provides for the recovery of certain costs applicable to both sales and transportation customers.

• A Revenue Decoupling Mechanism (RDM) at NSTAR Gas that reconciles annual base distribution rate recovery amounts recovered from customers to the pre-established level of baseline distribution delivery service revenue requirement approved by the DPU in 2015. The pre-established level of baseline distribution delivery service revenue requirement is also subject to adjustment in accordance with provisions of the November 2015 NSTAR Gas distribution rate case.

• A Purchased Gas Adjustment (PGA) clause, which is evaluated monthly and allows Yankee Gas to recover the costs of the procurement of natural gas for its firm and seasonal customers.  Differences between actual natural gas costs and collection amounts on August 31st of each year are deferred and then recovered from, or refunded to, customers during the following year.  Carrying charges on outstanding balances are calculated using Yankee Gas' weighted average cost of capital in accordance with the directives of the PURA.

• A Conservation Adjustment Mechanism (CAM) at Yankee Gas, which allows 100 percent recovery of conservation costs through this mechanism including program incentives to promote energy efficiency, as well as recovery of any lost revenues associated with implementation of energy conservation measures.  A reconciliation of CAM revenues to expenses is performed annually with any difference being recovered from, or refunded to, customers with carrying charges during the following year.

• A Gas System Improvement (GSI) reconciliation mechanism at Yankee Gas, which collects the costs of certain Distribution Integrity Management Program (DIMP) and core capital plant in service above and beyond the level that is recovered through the distribution charge. The GSI is adjusted and reconciled annually, with any differences refunded to, or recovered from, customers.

• A RDM at Yankee Gas that reconciles annual base distribution rate recovery amounts recovered from customers to the pre-established level of baseline distribution delivery service revenue requirement approved by the PURA effective January 1, 2019, January 1, 2020 and January 1, 2021. The pre-established level of baseline distribution delivery service revenue requirement is also subject to adjustment at each of these dates in accordance with provisions of the 2018 rate case settlement agreement.

• A System Expansion Rate (SER) Reconciliation Mechanism at Yankee Gas, which compares distribution system expansion investment costs and revenues for new customers, with the level projected in current distribution customer rates.  This reconciliation is performed annually and customer rates are adjusted accordingly.

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NSTAR Gas purchases financial contracts based on the New York Mercantile Exchange (NYMEX) natural gas futures in order to reduce cash flow variability associated with the price for approximately one-third of its normal winter season natural gas supplies.  These purchases are made under a program approved by the DPU in 2006.  This practice attempts to minimize the impact of fluctuations in natural gas prices to NSTAR Gas' firm natural gas customers.  These financial contracts do not procure natural gas supply.  All costs incurred or benefits realized when these contracts are settled are included in the CGAC.

NSTAR Gas is subject to SQ metrics that measure safety, reliability and customer service and could be required to pay to customers a SQ charge of up to 2.5 percent of annual distribution revenues for failing to meet such metrics.  NSTAR Gas will not be required to pay a SQ charge for its 2019 performance as it achieved results at or above target for all of its SQ metrics in 2019.

Distribution Rate Case: On November 8, 2019, NSTAR Gas filed its application with the DPU, which sought a distribution rate increase of $38.0 million effective October 1, 2020. As part of this filing, NSTAR Gas also proposed to continue its ongoing Gas System Enhancement Program (GSEP), include the GSEP investments since 2015 into base rates, and implement a performance-based ratemaking plan. A final decision from the DPU is expected by September 30, 2020.

Yankee Gas distribution rates were set in a December 2018 PURA approved rate case settlement agreement, with rates effective November 15, 2018. The 2018 Yankee Gas settlement agreement required Yankee Gas to implement a Distribution Integrity Management Program (DIMP) cost recovery mechanism to further invest capital to replace aging infrastructure. The DIMP mechanism allows for recovery of costs associated with capital additions of approximately $26 million to $37 million annually, which is incremental to the $150 million included in base distribution rate base per year. The settlement agreement also provides Yankee Gas the opportunity to seek recovery of additional capital spending above these levels with PURA approval. PURA ordered an accelerated replacement program for Yankee Gas to fully replace its cast iron and bare steel facilities in 11 years and fully replace copper services and certain steel mains and services in 14 years. Yankee Gas was also authorized to continue its ongoing natural gas system expansion program, implement a revenue decoupling rate mechanism, and recover merger costs. The settlement agreement included a regulatory ROE of 9.3 percent. In addition, the distribution rates charged to customers were adjusted to reflect the prospective impacts of the lower federal corporate income tax rate, the overcollection of the lower income tax rate from January 1, 2018, and the EDIT from the Tax Cuts and Jobs Act. Although new rates were effective January 1, 2019, the provisions of the settlement agreement took effect November 15, 2018.

Natural Gas Replacement and Expansion

Massachusetts: Pursuant to Massachusetts legislation, in October of each year, NSTAR Gas files the GSEP with the DPU for the following construction year. NSTAR Gas' program accelerates the replacement of certain natural gas distribution facilities in the system to less than 25 years.  The GSEP includes a tariff that provides NSTAR Gas an opportunity to collect the costs for the program on an annual basis through a reconciling factor.  On April 30th each year, the DPU approves the GSEP rate recovery factor that goes into effect on May 1st.

NSTAR Gas' distribution rate case application filed on November 8, 2019 included a proposal to include GSEP additions through 2018 into base distribution rates and to continue the operation of the GSEP mechanism for GSEP investments made after 2018. In addition, the filing included a proposal for a customer connection surcharge, which would be used to reduce up-front contribution in aid of construction (CIAC) costs for customers seeking to connect to the company’s distribution system. A final decision from the DPU is expected by September 30, 2020.

Connecticut: Yankee Gas' December 2018 PURA approved rate case settlement agreement included an accelerated pipeline replacement cost recovery program. The Gas System Improvement (“GSI”) rate recovers accelerated pipeline replacement as well as other capital investment through an annual reconciliation. The Company filed its first GSI reconciliation on March 1, 2019 for rates effective April 1, 2019 and will continue to file annually on March 1 for rates effective April 1.

In 2013, in accordance with Connecticut law and regulations, the PURA approved a comprehensive joint natural gas infrastructure expansion plan (the "Expansion Plan") filed by Yankee Gas and other Connecticut natural gas distribution companies.  In January 2015, the PURA approved a joint settlement agreement proposed by Yankee Gas and other Connecticut natural gas distribution companies and regulatory agencies that clarified the procedures and oversight criteria applicable to the Expansion Plan.  Yankee Gas received approval from PURA for its 2014, 2015 and 2016 System Expansion Reconciliations. Yankee Gas filed its 2017 and 2018 System Expansion Reconciliations in March 2018 and March 2019, respectively. Yankee Gas is now awaiting an order and does not anticipate any material changes to its 2017 and 2018 Reconciliations.

Sources and Availability of Natural Gas Supply

NSTAR Gas maintains a flexible resource portfolio consisting of natural gas supply contracts, transportation contracts on interstate pipelines, market area storage and peaking services. NSTAR Gas purchases transportation, storage, and balancing services from Tennessee Gas Pipeline Company and Algonquin Gas Transmission Company, as well as other upstream pipelines that transport natural gas from major natural gas producing regions in the U.S., including the Gulf Coast, Mid-continent region, and Appalachian Shale supplies to the final delivery points in the NSTAR Gas service area. NSTAR Gas purchases all of its natural gas supply under a firm, competitively bid annual portfolio management contract. In addition to the firm transportation and natural gas storage supplies discussed above, NSTAR Gas utilizes on-system LNG facilities to meet its winter peaking demands. These LNG facilities are located within NSTAR Gas' distribution system and are used to liquefy and store pipeline natural gas during the warmer months for vaporization and use during the heating season. During the summer injection season, excess pipeline capacity and supplies are used to deliver and store natural gas in market area underground storage facilities located in Maryland and Pennsylvania. Stored natural gas is withdrawn during the winter season to supplement flowing pipeline supplies in order to meet firm heating demand. NSTAR Gas has firm underground storage contracts and total storage capacity entitlements of approximately 6.6 Bcf, of which 3.5 Bcf LNG storage is provided by Hopkinton LNG Corp. in facilities located in Hopkinton and Acushnet, Massachusetts.

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The PURA requires Yankee Gas to meet the needs of its firm customers under all weather conditions. Specifically, Yankee Gas must structure its supply portfolio to meet firm customer needs under a design day scenario (defined as the coldest day in 30 years) and under a design year scenario (defined as the average of the four coldest years in the last 30 years). Yankee Gas also maintains a flexible resource portfolio consisting of natural gas supply contracts, transportation contracts on interstate pipelines, off-system storage and its on-system 1.2 Bcf LNG storage facility to meet consumption needs during the coldest days of winter. Yankee Gas obtains its interstate capacity from the three interstate pipelines that directly serve Connecticut: the Algonquin, Tennessee and Iroquois Pipelines, which connect to other upstream pipelines that transport natural gas from major natural gas producing regions, including the Gulf Coast, Mid-continent, Canadian regions and Appalachian Shale supplies.

Based on information currently available regarding projected growth in demand and estimates of availability of future supplies of pipeline natural gas, each of NSTAR Gas and Yankee Gas believes that in order to meet the long-term firm customer requirements in a reliable manner will necessitate a combination of pipeline, storage, and non-pipeline solutions.

WATER DISTRIBUTION SEGMENT

Eversource Water Ventures, Inc., a Connecticut corporation, through its wholly-owned subsidiary, Eversource Aquarion Holdings, Inc. (Aquarion), operates three separate regulated water utilities in Connecticut (Aquarion Water Company of Connecticut, or “AWC-CT”), Massachusetts (Aquarion Water Company of Massachusetts, or “AWC-MA”) and New Hampshire (Aquarion Water Company of New Hampshire, or “AWC-NH”). These regulated companies provide water services to approximately 229,000 residential, commercial, industrial, municipal and fire protection and other customers, in 60 towns and cities in Connecticut, Massachusetts and New Hampshire. As of December 31, 2019, approximately 87 percent of Aquarion’s customers were based in Connecticut.

Rates

Aquarion's water utilities are subject to regulation by the PURA, the DPU and the NHPUC in Connecticut, Massachusetts and New Hampshire, respectively. These regulatory agencies have jurisdiction over, among other things, rates, certain dispositions of property and plant, mergers and consolidations, issuances of long-term securities, standards of service and construction and operation of facilities.

Aquarion’s general rate structure consists of various rate and service classifications covering residential, commercial, industrial, and municipal and fire protection services.

The rates established by the PURA, DPU and NHPUC are comprised of the following:

• A base rate, which is comprised of fixed charges based on meter/fire connection sizes, as well as volumetric charges based on the amount of water sold. Together these charges are designed to recover the full cost of service resulting from a general rate proceeding.

• In Connecticut, a revenue adjustment mechanism (“RAM”) that reconciles earned revenues, with certain allowed adjustments, on an annual basis, to the revenue requirement approved by the PURA in AWC-CT’s last rate case (2013), which is an annual amount of $178.0 million.

• In Connecticut and New Hampshire, a water infrastructure conservation adjustment (“WICA”) charge, and in Massachusetts an annual main replacement adjustment mechanism (“MRAM”) charge, which is applied between rate case proceedings and seeks recovery of allowed costs associated with eligible infrastructure improvement projects placed in-service. The WICA is updated semi-annually in Connecticut and annually in New Hampshire, with any differences refunded to, or recovered from, customers.

• In Massachusetts, treatment plant surcharges, which are a series of three surcharges (one fixed and two volumetric in nature) that are designed to recover certain operating costs and the costs of the lease of the treatment plant located in Hingham.  These surcharges are applicable only to customers in Hingham, Hull and Cohasset.

Sources and Availability of Water Supply

Our water utilities obtain their water supplies from owned surface water sources (reservoirs) and groundwater supplies (wells) with a total supply yield of approximately 131 million gallons per day, as well as water purchased from other water suppliers. Approximately 99 percent of our annual production is self-supplied and processed at 10 surface water treatment plants and numerous well stations, which are all located in Connecticut, Massachusetts, and New Hampshire.

The capacities of Aquarion’s sources of supply, and water treatment, pumping and distribution facilities, are considered sufficient to meet the present requirements of Aquarion’s customers under normal conditions. On occasion, drought declarations are issued for portions of Aquarion’s service territories in response to extended periods of dry weather conditions.

OFFSHORE WIND PROJECTS

Eversource's offshore wind business includes ownership interests in North East Offshore and Bay State Wind, which together hold power purchase agreements (PPAs) and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind projects, as well as offshore leases through the U.S. Bureau of Ocean Energy Management (BOEM). Our offshore wind projects are being developed and constructed through a joint and equal partnership with Ørsted. This partnership also participates in opportunities for solicitations for offshore wind energy in the Northeast U.S.

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On February 8, 2019, Eversource and Ørsted entered into an equal partnership to acquire key offshore wind assets in the Northeast. Eversource has a 50 percent ownership interest in North East Offshore, which holds the Revolution Wind and South Fork Wind projects, as well as a 257 square-mile lease off the coasts of Massachusetts and Rhode Island. Eversource also has a 50 percent ownership interest in Bay State Wind, which holds the Sunrise Wind project. Bay State Wind's separate 300-square-mile ocean lease is located approximately 25 miles south of the coast of Massachusetts adjacent to the North East Offshore area. In aggregate, the Bay State Wind and the North East Offshore lease sites jointly-owned by Eversource and Ørsted could eventually develop at least 4,000 MW of clean, renewable offshore wind energy.

Revolution Wind is a 704 MW offshore wind power project located approximately 15 miles south of the Rhode Island coast, and South Fork Wind is a 130 MW offshore wind power project located approximately 35 miles east of Long Island. Sunrise Wind is an 880 MW offshore wind facility, which will be developed 35 miles east of Montauk Point, Long Island. The completion dates for these projects are subject to federal permitting through BOEM, engineering, state siting and permitting in New York and Rhode Island, and finalizing a PPA amendment in New York. For more information on these projects, see "Business Development and Capital Expenditures – Offshore Wind Business" in the accompanying Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.

NATURAL GAS TRANSMISSION PROJECT

Access Northeast was a natural gas pipeline and storage project jointly owned by Eversource, Enbridge, Inc. (Enbridge) and National Grid plc (National Grid), through Algonquin Gas Transmission, LLC (AGT). In 2018, management determined that the future cash flows of the Access Northeast project were uncertain and could no longer be reasonably estimated and that the book value of our equity method investment was not recoverable. As a result, Eversource recorded an other-than-temporary impairment of $32.9 million pre-tax within Other Income, Net on our statement of income in 2018, which represented the full carrying value of our equity method investment. On April 1, 2019, in accordance with a provision of the AGT LLC operating agreement, the Access Northeast project was terminated. For further information, see "Critical Accounting Policies - Access Northeast" in the accompanying Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.

PROJECTED CAPITAL EXPENDITURES

We project to make capital expenditures of $14.19 billion from 2020 through 2024, of which we expect $8.63 billion to be in our electric and natural gas distribution segments, $3.98 billion to be in our electric transmission segment and $0.69 billion to be in our water distribution segment. We also project to invest $0.90 billion in information technology and facilities upgrades and enhancements. These projections do not include any expected investments related to our offshore wind partnership.  

FINANCING

Our credit facilities and indentures require that Eversource parent and certain of its subsidiaries, including CL&P, NSTAR Electric, PSNH, NSTAR Gas, Yankee Gas, and Aquarion, comply with certain financial and non-financial covenants as are customarily included in such agreements, including maintaining a ratio of consolidated debt to total capitalization of no more than 65 percent.  All of these companies currently are, and expect to remain, in compliance with these covenants.  

As of December 31, 2019, $296.1 million of Eversource's long-term debt, including $95.0 million, $50.0 million, $150.0 million, and $1.1 million for NSTAR Electric, Yankee Gas, NSTAR Gas and Aquarion, respectively, will mature within the next 12 months.

NUCLEAR FUEL STORAGE

CL&P, NSTAR Electric, PSNH, and several other New England electric utilities are stockholders in three inactive regional nuclear generation companies, CYAPC, MYAPC and YAEC (collectively, the Yankee Companies).  The Yankee Companies have completed the physical decommissioning of their respective nuclear power facilities and are now engaged in the long-term storage of their spent nuclear fuel.  The Yankee Companies fund these costs through litigation proceeds received from the DOE and, to the extent necessary, through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. CL&P, NSTAR Electric and PSNH, in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies collect amounts that we believe are adequate to recover the remaining plant closure and fuel storage cost estimates for the respective plants. We believe CL&P and NSTAR Electric will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers.

We consolidate the assets and obligations of CYAPC and YAEC on our consolidated balance sheet because our ownership and voting interests are more than 50 percent of each of these companies.  

OTHER REGULATORY AND ENVIRONMENTAL MATTERS

General

We are regulated in virtually all aspects of our business by various federal and state agencies, including FERC, the SEC, and various state and/or local regulatory authorities with jurisdiction over the industry and the service areas in which each of our companies operates, including the PURA, which has jurisdiction over CL&P, Yankee Gas, and Aquarion, the NHPUC, which has jurisdiction over PSNH and Aquarion, and the DPU, which has jurisdiction over NSTAR Electric, NSTAR Gas, and Aquarion.

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Environmental Regulation

We are subject to various federal, state and local requirements with respect to water quality, air quality, toxic substances, hazardous waste and other environmental matters.  Additionally, major generation and transmission facilities may not be constructed or significantly modified without a review of the environmental impact of the proposed construction or modification by the applicable federal or state agencies.  

Renewable Portfolio Standards

Each of the states in which we do business also has Renewable Portfolio Standards (RPS) requirements, which generally require fixed percentages of our energy supply to come from renewable energy sources such as solar, wind, hydropower, landfill gas, fuel cells and other similar sources.

New Hampshire's RPS provision requires increasing percentages of the electricity sold to retail customers to have direct ties to renewable sources. In 2019, the total RPS obligation was 19.7 percent and it will ultimately reach 25.2 percent in 2025. The costs of the RECs are recovered by PSNH through rates charged to customers.

Similarly, Connecticut's RPS statute requires increasing percentages of the electricity sold to retail customers to have direct ties to renewable sources. In 2019, the total RPS obligation was 27.5 percent and will ultimately reach 48 percent in 2030. CL&P is permitted to recover any costs incurred in complying with RPS from its customers through its GSC rate.

Massachusetts' RPS program also requires electricity suppliers to meet renewable energy standards. For 2019, the requirement was 24.94 percent, and will ultimately reach 38.96 percent in 2025. NSTAR Electric is permitted to recover any costs incurred in complying with RPS from its customers through rates. NSTAR Electric also owns renewable solar power facilities. The RECs generated from NSTAR Electric's solar power facilities are sold to other energy suppliers, and the proceeds from these sales are credited back to customers.

Hazardous Materials Regulations

We have recorded a liability for what we believe, based upon currently available information, is our reasonably estimable environmental investigation, remediation, and/or Natural Resource Damages costs for waste disposal sites for which we have probable liability. Under federal and state law, government agencies and private parties can attempt to impose liability on us for recovery of investigation and remediation costs at hazardous waste sites. As of December 31, 2019, the liability recorded for our reasonably estimable and probable environmental remediation costs for known sites needing investigation and/or remediation, exclusive of recoveries from insurance or from third parties, was $81.0 million, representing 57 sites. These costs could be significantly higher if additional remediation becomes necessary or when additional information as to the extent of contamination becomes available.

The most significant liabilities currently relate to future clean-up costs at former MGP facilities. These facilities were owned and operated by our predecessor companies from the mid-1800's to mid-1900's. By-products from the manufacture of natural gas using coal resulted in fuel oils, hydrocarbons, coal tar, purifier wastes, metals and other waste products that may pose a potential risk to human health and the environment. We currently have partial or full ownership responsibilities at former MGP sites that have a reserve balance of $67.9 million of the total $81.0 million as of December 31, 2019. MGP costs are recoverable through rates charged to our customers.

Electric and Magnetic Fields  

For more than twenty years, published reports have discussed the possibility of adverse health effects from electric and magnetic fields (EMF) associated with electric transmission and distribution facilities and appliances and wiring in buildings and homes.  Although weak health risk associations reported in some epidemiology studies remain unexplained, most researchers, as well as numerous scientific review panels, considering all significant EMF epidemiology and laboratory studies, have concluded that the available body of scientific information does not support the conclusion that EMF affects human health.

In accordance with recommendations of various regulatory bodies and public health organizations, we reduce EMF associated with new transmission lines by the use of designs that can be implemented without additional cost or at a modest cost.  We do not believe that other capital expenditures are appropriate to minimize unsubstantiated risks.

Global Climate Change and Greenhouse Gas Emission Issues

Global climate change and greenhouse gas emission issues have received an increased focus from state governments and the federal government. The EPA initiated a rulemaking addressing greenhouse gas emissions and, on December 7, 2009, issued a finding that concluded that greenhouse gas emissions are "air pollution" that endangers public health and welfare and should be regulated.  The EPA has mandated greenhouse gas emission reporting beginning in 2011 for emissions for certain aspects of our business including volume of gas supplied to large customers and fugitive emissions of SF6 gas and methane.

We are continually evaluating the regulatory risks and regulatory uncertainty presented by climate change concerns.  Such concerns could potentially lead to additional rules and regulations that impact how we operate our general utility business.  These could include federal "cap and trade" laws, carbon taxes, and fuel and energy taxes.  We expect that any costs of these rules and regulations would be recovered from customers.

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INFORMATION ABOUT OUR EXECUTIVE OFFICERS

For information about Eversource Energy's executive officers, see Item 10, Directors, Executive Officers and Corporate Governance, included in this Annual Report on Form 10-K.

EMPLOYEES

As of December 31, 2019, Eversource Energy employed a total of 8,234 employees, excluding temporary employees, of which 1,343 were employed by CL&P, 1,604 were employed by NSTAR Electric, and 742 were employed by PSNH. Approximately 50 percent of our employees are members of the International Brotherhood of Electrical Workers, the Utility Workers Union of America or The United Steelworkers, and are covered by nine collective bargaining agreements.

INTERNET INFORMATION

Our website address is www.eversource.com.  We make available through our website a link to the SEC's EDGAR website (http://www.sec.gov/edgar/searchedgar/companysearch.html), at which site Eversource's, CL&P's, NSTAR Electric's and PSNH's combined Annual Reports on Form 10-K, combined Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to those reports may be reviewed. Information contained on the Company's website or that can be accessed through the website is not incorporated into and does not constitute a part of this Annual Report on Form 10-K.  Printed copies of these reports may be obtained free of charge by writing to our Investor Relations Department at Eversource Energy, 107 Selden Street, Berlin, CT 06037.  

Item 1A.    Risk Factors

In addition to the matters set forth under "Safe Harbor Statement Under the Private Securities Litigation Reform Act of 1995" included immediately prior to Item 1, Business, above, we are subject to a variety of significant risks. Our susceptibility to certain risks, including those discussed in detail below, could exacerbate other risks. These risk factors should be considered carefully in evaluating our risk profile.

Cyberattacks, including acts of war or terrorism, targeted directly on or indirectly affecting our systems or the systems of third parties on which we rely, could severely impair operations, negatively impact our business, lead to the disclosure of confidential information and adversely affect our reputation.

A successful cyberattack on the information technology systems that control our transmission and distribution systems or other assets could impair or prevent us from managing these systems and facilities, operating our systems effectively, or properly managing our data, networks and programs. The breach of certain information technology systems could adversely affect our ability to correctly record, process and report financial information. A major cyber incident could result in significant expenses to investigate and to repair system damage or security breaches and could lead to litigation, fines, other remedial action, heightened regulatory scrutiny and damage to our reputation.

We have instituted safeguards to protect our information technology systems and assets. We devote substantial resources to network and application security, encryption and other measures to protect our computer systems and infrastructure from unauthorized access or misuse and interface with numerous external entities to improve our cybersecurity situational awareness. The FERC, through the North American Electric Reliability Corporation (NERC), requires certain safeguards to be implemented to deter cyberattacks. These safeguards may not always be effective due to the evolving nature of cyberattacks. We maintain cyber insurance to cover damages and defense costs related to breaches of networks or operational technology, but it may be insufficient to cover all losses.

Any such cyberattacks could result in loss of service to customers and a significant decrease in revenues, which could have a material adverse impact on our financial position, results of operations and cash flows.

Strategic development opportunities associated with offshore wind or investment opportunities in electric transmission or clean-energy opportunities may not be successful, and projects may not commence operation as scheduled or be completed, which could have a material adverse effect on our business prospects.

We are pursuing broader strategic development investment opportunities that will benefit the Northeast region related to the construction of offshore wind electric generation facilities, and investment opportunities in electric transmission facilities and other clean-energy infrastructure. The development of these activities involves numerous significant risks around schedule, cost, capacity factors, tax strategies and permitting (both on and offshore). Various external factors could result in increased costs or result in delays or cancellation of these projects. Risks include both federal and state regulatory approval processes, new legislation impacting the industry, changes to federal income tax laws, economic events or factors, environmental and community concerns, design and siting issues, difficulties in obtaining required rights of way, competition from incumbent utilities and other entities, and actions of our strategic partners. Should any of these factors result in significant delays or cancellations, our financial position, results of operations, and cash flows could be materially adversely affected, or our future growth opportunities may not be realized as anticipated.

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Eversource has a joint and equal partnership with Ørsted for the development and operation of three offshore wind projects. Offshore wind is currently an emerging industry in the U.S., but it has a very robust operational and construction history in Europe. As such, siting, permitting, tax legislation, and supply chain are currently being addressed for the first time in the U.S. The projects currently being developed by our partnership may not achieve the results we anticipate. The partnership’s ability to generate revenue from offshore wind projects depends on meeting our construction schedules, controlling cost overruns, maintaining continuing interconnection arrangements, power purchase agreements, or other market mechanisms as well as interconnecting utility and Regional Transmission Organizations rules, policies, procedures and FERC tariffs that permit future offshore wind project operations. After projects are placed in operation, capacity factors will directly affect revenues generated from these investments. Other factors that may have an adverse impact on our anticipated project returns include significant schedule delays resulting from federal, state or local permitting processes. Specifically, the approval from the Bureau of Ocean Energy Management (BOEM) is a critical path item in the projects' timeline. Any changes to tax laws or to Eversource’s ability to monetize tax attributes associated with these projects could also have a material adverse effect on cash flows and project returns.

As a result of legislative and regulatory changes, the states in which we provide service have implemented new selection procedures for new major electric transmission, offshore wind and other clean energy facilities. These procedures require the review of competing projects and permit the selection of only those projects that are expected to provide the greatest benefit to customers. If the projects in which we have invested are not selected for construction, or even if our projects are selected, then legislative or regulatory actions could result in our projects not being probable of entering the construction phase, which could have a material adverse effect on our future financial position, results of operations and cash flows.

Physical attacks, including acts of war or terrorism, both threatened and actual, could adversely affect our ability to operate our systems and could adversely affect our financial results and liquidity.

Physical attacks, including acts of war or terrorism, both threatened and actual, that damage our transmission and distribution systems or other assets could negatively impact our ability to transmit or distribute energy, water, natural gas, or operate our systems efficiently or at all. Because our electric transmission systems are part of an interconnected regional grid, we face the risk of widespread blackouts due to grid disturbances or disruptions on a neighboring interconnected system. Similarly, our natural gas distribution system is connected to transmission pipelines, not owned by Eversource, if there was an attack on the transmission pipelines, it could impact our ability to deliver natural gas. If our assets were physically damaged and were not recovered in a timely manner, it could result in a loss of service to customers, a significant decrease in revenues, significant expense to repair system damage, costs associated with governmental actions in response to such attacks, and liability claims, all of which could have a material adverse impact on our financial position, results of operations and cash flows. We maintain property and liability insurance, but it may be insufficient to cover all losses.

The actions of regulators and legislators can significantly affect our earnings, liquidity and business activities.

The rates that our electric, natural gas and water companies charge their customers are determined by their state regulatory commissions and by the FERC. These commissions also regulate the companies' accounting, operations, the issuance of certain securities and certain other matters. The FERC also regulates the transmission of electric energy, the sale of electric energy at wholesale, accounting, issuance of certain securities and certain other matters, including reliability standards through NERC.

Under state and federal law, our electric, natural gas and water companies are entitled to charge rates that are sufficient to allow them an opportunity to recover their prudently incurred operating and capital costs and a reasonable rate of return on invested capital, to attract needed capital and maintain their financial integrity, while also protecting relevant public interests. Each of these companies prepares and submits periodic rate filings with their respective regulatory commissions for review and approval, which allows for various entities to challenge our current or future rates, structures or mechanisms and could alter or limit the rates we are allowed to charge our customers and may not match the timing of when costs are incurred. Additionally, a catastrophic event not involving Eversource could result in our regulators and legislators imposing additional requirements that may lead to additional costs for the Company.

There is no assurance that regulators will approve the recovery of all costs incurred by our electric, natural gas and water companies, including costs for construction, operation and maintenance, as well as a reasonable return on their respective regulated assets. The amount of costs incurred by the companies, coupled with increases in fuel and energy prices, could lead to consumer or regulatory resistance to the timely recovery of such costs, thereby adversely affecting our financial position, results of operations and cash flows.

The FERC has jurisdiction over our transmission costs recovery and our allowed ROEs. Certain outside parties have filed four complaints against all electric companies under the jurisdiction of ISO-NE alleging that our allowed ROEs are unjust and unreasonable. An adverse decision in any of these four complaints could adversely affect our financial position, results of operations and cash flows.

FERC's policy has encouraged competition for transmission projects, even within existing service territories of electric companies. Implementation of FERC's goals, including within our service territories, may expose us to competition for construction of transmission projects, additional regulatory considerations, and potential delay with respect to future transmission projects, which may adversely affect our results of operations and lower rate base growth.

Changes in tax laws, as well as the potential tax effects of business decisions could negatively impact our business, results of operations (including our expected project returns from our planned offshore wind facilities), financial condition and cash flows.

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We outsource certain business functions to third-party suppliers and service providers, and substandard performance by those third parties could harm our business, reputation and results of operations.

We outsource certain services to third parties in areas including information technology, transaction processing, human resources, payroll and payroll processing and other operational areas. Outsourcing of services to third parties could expose us to substandard quality of service delivery or substandard deliverables, which may result in missed deadlines or other timeliness issues, non-compliance (including with applicable legal requirements and industry standards) or reputational harm, which could negatively impact our results of operations. We also continue to pursue enhancements to standardize our systems and processes. If any difficulties in the operation of these systems were to occur, they could adversely affect our results of operations, or adversely affect our ability to work with regulators, unions, customers or employees.

The effects of climate change, including severe storms, could cause significant damage to any of our facilities requiring extensive expenditures, the recovery for which is subject to approval by regulators.

Climate change creates physical and financial risks to our operations. Physical risks from climate change may include an increase in sea levels and changes in weather conditions, such as changes in precipitation and extreme weather events including drought. Customers’ energy needs vary with weather conditions, primarily temperature and humidity. For residential customers, heating and cooling represent their largest energy use. For water customers, conservation measures imposed by the communities we serve could impact water usage. To the extent weather conditions are affected by climate change, customers’ energy and water usage could increase or decrease depending on the duration and magnitude of the changes.

Severe weather, such as ice and snow storms, hurricanes, droughts, and other natural disasters, may cause outages and property damage, which may require us to incur additional costs that may not be recoverable from customers. The cost of repairing damage to our operating subsidiaries' facilities and the potential disruption of their operations due to storms, natural disasters or other catastrophic events could be substantial, particularly as regulators and customers demand better and quicker response times to outages. If, upon review, any of our state regulatory authorities finds that our actions were imprudent, some of those restoration costs may not be recoverable from customers. The inability to recover a significant amount of such costs could have an adverse effect on our financial position, results of operations and cash flows. We maintain property insurance, but it may be insufficient to cover all losses.

Our transmission and distribution systems may not operate as expected, and could require unplanned expenditures, which could adversely affect our financial position, results of operations and cash flows.

Our ability to properly operate our transmission and distribution systems is critical to the financial performance of our business. Our transmission and distribution businesses face several operational risks, including the breakdown, failure of, or damage to operating equipment, information technology systems, or processes, especially due to age; labor disputes; disruptions in the delivery of electricity, natural gas and water; increased capital expenditure requirements, including those due to environmental regulation; catastrophic events such as fires, explosions, a solar event, an electromagnetic event, or other similar occurrences; extreme weather conditions beyond equipment and plant design capacity; human error; and potential claims for property damage or personal injuries beyond the scope of our insurance coverage. Many of our transmission projects are expected to alleviate identified reliability issues and reduce customers' costs. However, if the in-service date for one or more of these projects is delayed due to economic events or factors, or regulatory or other delays, the risk of failures in the electricity transmission system may increase. Any failure of our transmission and distribution systems to operate as planned may result in increased capital costs, reduced earnings or unplanned increases in operation and maintenance costs. The inability to recover a significant amount of such costs could have an adverse effect on our financial position, results of operations and cash flows.

New technology and alternative energy sources could adversely affect our operations and financial results.

Advances in technology that reduce the costs of alternative methods of producing electric energy to a level that is competitive with that of current electric production methods, could result in loss of market share and customers, and may require us to make significant expenditures to remain competitive. These changes in technology could also alter the channels through which electric customers buy or utilize energy, which could reduce our revenues or increase our expenses. Economic downturns or periods of high energy supply costs typically can lead to the development of legislative and regulatory policy designed to promote reductions in energy consumption and increased energy efficiency and self-generation by customers.

Contamination of our water supplies, the failure of dams on reservoirs providing water to our customers, or requirements to repair, upgrade or dismantle any of these dams, may disrupt our ability to distribute water to our customers and result in substantial additional costs, which could adversely affect our financial condition, and results of operations.

Our water supplies, including water provided to our customers, are subject to possible contamination from naturally occurring compounds or man-made substances.

Our water systems include impounding dams and reservoirs of various sizes. Although we believe our dams are structurally sound and well-maintained, significant damage to these facilities, or a significant decrease in the water in our reservoirs, could adversely affect our ability to provide water to our customers until the facilities and a sufficient amount of water in our reservoirs can be restored. A failure of a dam could result in personal injuries and downstream property damage for which we may be liable. The failure of a dam would also adversely affect our ability to supply water in sufficient quantities to our customers. Any losses or liabilities incurred due to a failure of one of our dams may not be recoverable in rates and may have a

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material adverse effect on our financial condition, results of operations and cash flows. We maintain liability insurance, but it may be insufficient to cover all losses.

The unauthorized access to and the misappropriation of confidential and proprietary customer, employee, financial or system operating information could adversely affect our business operations and adversely impact our reputation.

In the regular course of business, we, and our third-party suppliers, maintain sensitive customer, employee, financial and system operating information. We are required by various federal and state laws to safeguard this information. Cyber intrusions, security breaches, theft or loss of this information by cybercrime or otherwise could lead to the release of critical operating information or confidential customer or employee information, which could adversely affect our business operations or adversely impact our reputation, and could result in significant costs, fines and litigation. We maintain cyber insurance to cover damages and defense costs arising from unauthorized disclosure of, or failure to protect, private information, as well as costs for notification to, or for credit monitoring of, customers, employees and other persons in the event of a breach of private information. This insurance covers amounts paid to avert, prevent or stop a network attack or the disclosure of personal information, and costs of a qualified forensics firm to determine the cause, source and extent of a network attack or to investigate, examine and analyze our network to find the cause, source and extent of a data breach, but it may be insufficient to cover all losses. While we have implemented measures designed to prevent network attacks and mitigate their effects should they occur, these measures may not be effective due to the continually evolving nature of efforts to access confidential information.

Our counterparties may not meet their obligations to us or may elect to exercise their termination rights, which could adversely affect our earnings.

We are exposed to the risk that counterparties to various arrangements that owe us money, have contracted to supply us with energy or other commodities or services, or that work with us as strategic partners, including on significant capital projects, will not be able to perform their obligations, will terminate such arrangements or, with respect to our credit facilities, fail to honor their commitments. Should any of these counterparties fail to perform their obligations or terminate such arrangements, we might be forced to replace the underlying commitment at higher market prices and/or have to delay the completion of, or cancel, a capital project. Should any lenders under our credit facilities fail to perform, the level of borrowing capacity under those arrangements could decrease. In any such events, our financial position, results of operations, or cash flows could be adversely affected.

Our goodwill is recorded at an amount that, if impaired and written down, could adversely affect our future operating results and total capitalization.

We have a significant amount of goodwill on our consolidated balance sheet, which, as of December 31, 2019, totaled $4.4 billion. The carrying value of goodwill represents the fair value of an acquired business in excess of the fair value of identifiable assets and liabilities as of the acquisition date. We test our goodwill balances for impairment on an annual basis or whenever events occur, or circumstances change that would indicate a potential for impairment. A determination that goodwill is deemed to be impaired would result in a non-cash charge that could materially adversely affect our financial position, results of operations and total capitalization. The annual goodwill impairment test in 2019 resulted in a conclusion that our goodwill was not impaired.

We are exposed to significant reputational risks, which make us vulnerable to increased regulatory oversight or other sanctions.

Because utility companies, including our electric, natural gas and water utility subsidiaries, have large customer bases, they are subject to adverse publicity focused on the reliability of their distribution services and the speed with which they are able to respond to electric outages, natural gas leaks and similar interruptions caused by storm damage or other unanticipated events. Adverse publicity of this nature could harm our reputation and the reputation of our subsidiaries; may make state legislatures, utility commissions and other regulatory authorities less likely to view us in a favorable light; and may cause us to be subject to less favorable legislative and regulatory outcomes or increased regulatory oversight. Unfavorable regulatory outcomes can include more stringent laws and regulations governing our operations, such as reliability and customer service quality standards or vegetation management requirements, as well as fines, penalties or other sanctions or requirements.

Limits on our access to, and increases in, the cost of capital may adversely impact our ability to execute our business plan.

We use short-term debt and the long-term capital markets as a significant source of liquidity and funding for capital requirements not obtained from our operating cash flow. If access to these sources of liquidity becomes constrained, our ability to implement our business strategy could be adversely affected. In addition, higher interest rates would increase our cost of borrowing, which could adversely impact our results of operations. A downgrade of our credit ratings or events beyond our control, such as a disruption in global capital and credit markets, could increase our cost of borrowing and cost of capital or restrict our ability to access the capital markets and negatively affect our ability to maintain and to expand our businesses.

Costs of compliance with environmental laws and regulations, including those related to climate change, may increase and have an adverse effect on our business and results of operations.

Our subsidiaries' operations are subject to extensive federal, state and local environmental statutes, rules and regulations that govern, among other things, water quality, water discharges, the management of hazardous and solid waste, and air emissions. Compliance with these requirements requires us to incur significant costs relating to environmental monitoring, maintenance and upgrading of facilities, remediation and permitting.

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The costs of compliance with existing legal requirements or legal requirements not yet adopted may increase in the future. An increase in such costs, unless promptly recovered, could have an adverse impact on our business and our financial position, results of operations and cash flows.

For further information, see Item 1, Business - Other Regulatory and Environmental Matters, included in this Annual Report on Form 10-K.

The loss of key personnel, the inability to hire and retain qualified employees, or the failure to maintain a positive relationship with our workforce could have an adverse effect on our business, financial position and results of operations.

Our operations depend on the continued efforts of our employees. Retaining key employees and maintaining the ability to attract new employees are important to both our operational and financial performance. We cannot guarantee that any member of our management or any key employee at the Eversource parent or subsidiary level will continue to serve in any capacity for any particular period of time. In addition, a significant portion of our workforce in our subsidiaries, including many workers with specialized skills maintaining and servicing the electric, natural gas and water infrastructure, will be eligible to retire over the next five to ten years. Such highly skilled individuals cannot be quickly replaced due to the technically complex work they perform. We have developed strategic workforce plans to identify key functions and proactively implement plans to assure a ready and qualified workforce, but we cannot predict the impact of these plans on our ability to hire and retain key employees. Labor disputes, work stoppages or an inability to negotiate future collective bargaining agreements on commercially reasonable terms, as well as the intentional misconduct of employees or contractors, may also have an adverse effect on our business, financial position and results of operations.

Market performance or changes in assumptions may require us to make significant contributions to our pension and other postretirement benefit plans.

We provide a defined benefit pension plan and other postretirement benefits for a substantial number of employees, former employees and retirees. Our future pension obligations, costs and liabilities are highly dependent on a variety of factors, many of which are beyond our control. These factors include estimated investment returns, interest rates, discount rates, health care cost trends, benefit changes, salary increases and the demographics of plan participants. If our assumptions prove to be inaccurate, our future costs could increase significantly.  In addition, various factors, including underperformance of plan investments and changes in law or regulation, could increase the amount of contributions required to fund our pension plan in the future. Additional large funding requirements, when combined with the financing requirements of our construction program, could impact the timing, amounts, and number of future financings and negatively affect our financial position, results of operations and cash flows.

As a holding company with no revenue-generating operations, Eversource parent's liquidity is dependent on dividends from its subsidiaries, its commercial paper program, and its ability to access the long-term debt and equity capital markets.

Eversource parent is a holding company and as such, has no revenue-generating operations of its own. Its ability to meet its debt service obligations and to pay dividends on its common shares is largely dependent on the ability of its subsidiaries to pay dividends to, or repay borrowings from, Eversource parent, and/or Eversource parent's ability to access its commercial paper program or the long-term debt and equity capital markets. Prior to funding Eversource parent, the subsidiary companies have financial obligations that must be satisfied, including among others, their operating expenses, debt service, preferred dividends of certain subsidiaries, and obligations to trade creditors. Should the subsidiary companies not be able to pay dividends or repay funds due to Eversource parent, or if Eversource parent cannot access its commercial paper programs or the long-term debt and equity capital markets, Eversource parent's ability to pay interest, dividends and its own debt obligations would be restricted.

Item 1B.    Unresolved Staff Comments

We do not have any unresolved SEC staff comments.

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Item 2.    Properties

Transmission and Distribution System

As of December 31, 2019, Eversource and our electric operating subsidiaries owned the following:

	Electric Distribution	Electric Transmission
Eversource
Number of substations owned	486	77
Transformer capacity (in kVa)	42,891,000	16,149,000
Overhead lines (in circuit miles)	40,568	3,963
Capacity range of overhead transmission lines (in kV)	N/A	69 to 345
Underground lines (in circuit miles)	17,764	406
Capacity range of underground transmission lines (in kV)	N/A	69 to 345

	CL&P		NSTAR Electric		PSNH
	Distribution	Transmission	Distribution	Transmission	Distribution	Transmission
Number of substations owned	181	20	169	35	136	22
Transformer capacity (in kVa)	21,618,000	3,633,000	16,937,000	7,465,000	4,336,000	5,051,000
Overhead lines (in circuit miles)	16,942	1,675	11,427	1,247	12,199	1,041
Capacity range of overhead transmission lines (in kV)	N/A	69 to 345	N/A	69 to 345	N/A	115 to 345
Underground lines (in circuit miles)	6,722	137	9,076	268	1,966	1
Capacity range of underground transmission lines (in kV)	N/A	69 to 345	N/A	115 to 345	N/A	115

	Eversource	CL&P	NSTAR Electric	PSNH
Underground and overhead line transformers in service	628,219	291,415	171,362	165,442
Aggregate capacity (in kVa)	37,019,694	16,092,291	14,338,752	6,588,651

Electric Generating Plants

On January 10, 2018, Eversource and PSNH completed the sale of PSNH's thermal generation assets, including steam, internal combustion and biomass units. The sale of hydroelectric generation assets was completed on August 26, 2018. See Note 14, "Generation Asset Sale," in the accompanying Item 8, Financial Statements and Supplementary Data for further information.

As of December 31, 2019, NSTAR Electric owned the following solar power facilities:  

Type of Plant	Number of Sites	Year Installed	Claimed Capability** (kilowatts)
Solar Fixed Tilt, Photovoltaic	22	2010 - 2019	70,000

** Claimed capability represents the direct current nameplate capacity of the plants.

CL&P does not own any electric generating plants.

Natural Gas Distribution System

As of December 31, 2019, Yankee Gas owned 28 active gate stations, 206 district regulator stations, and approximately 3,445 miles of natural gas main pipeline. Yankee Gas also owns a liquefaction and vaporization plant and above ground storage tank with a storage capacity equivalent of 1.2 Bcf of natural gas in Waterbury, Connecticut.

As of December 31, 2019, NSTAR Gas owned 21 active gate stations, 164 district regulator stations, and approximately 3,302 miles of natural gas main pipeline. Hopkinton, another subsidiary of Eversource, owns a satellite vaporization plant and above ground storage tanks in Acushnet, Massachusetts (0.5 Bcf of natural gas). In addition, Hopkinton owns a liquefaction and vaporization plant with above ground storage tanks in Hopkinton, Massachusetts (3.0 Bcf of natural gas). Combined, the two plants' tanks have an aggregate storage capacity equivalent to 3.5 Bcf of natural gas that is provided to NSTAR Gas under contract.

Water Distribution System

Aquarion’s properties consist of water transmission and distribution mains and associated valves, hydrants and service lines, water treatment plants, pumping facilities, wells, tanks, meters, dams, reservoirs, buildings, and other facilities and equipment used for the operation of our systems, including the collection, treatment, storage, and distribution of water.

As of December 31, 2019, Aquarion owned and operated sources of water supply with a combined yield of approximately 131 million gallons per day; 3,639 miles of transmission and distribution mains; 10 surface water treatment plants; 31 dams; and 112 wellfields.

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Franchises

CL&P  Subject to the power of alteration, amendment or repeal by the General Assembly of Connecticut and subject to certain approvals, permits and consents of public authority and others prescribed by statute, CL&P has, subject to certain exceptions not deemed material, valid franchises free from burdensome restrictions to provide electric transmission and distribution services in the respective areas in which it is now supplying such service.

In addition to the right to provide electric transmission and distribution services as set forth above, the franchises of CL&P include, among others, limited rights and powers, as set forth under Connecticut law and the special acts of the General Assembly constituting its charter, to manufacture, generate, purchase and/or sell electricity at retail, including to provide Standard Service, Supplier of Last Resort service and backup service, to sell electricity at wholesale and to erect and maintain certain facilities on public highways and grounds, all subject to such consents and approvals of public authority and others as may be required by law. The franchises of CL&P include the power of eminent domain.  Connecticut law prohibits an electric distribution company from owning or operating generation assets.  However, under "An Act Concerning Electricity and Energy Efficiency," enacted in 2007, an electric distribution company, such as CL&P, is permitted to purchase an existing electric generating plant located in Connecticut that is offered for sale, subject to prior approval from the PURA and a determination by the PURA that such purchase is in the public interest.

NSTAR Electric  Through its charter, which is unlimited in time, NSTAR Electric has the right to engage in the business of delivering and selling electricity within its respective service territory, and has the power incidental thereto and is entitled to all the rights and privileges of and subject to the duties imposed upon electric companies under Massachusetts laws.  The locations in public ways for electric transmission and distribution lines are obtained from municipal and other state authorities who, in granting these locations, act as agents for the state. In some cases, the actions of these authorities are subject to appeal to the DPU.  The rights to these locations are not limited in time and are subject to the action of these authorities and the legislature.  Under Massachusetts law, no other entity may provide electric delivery service to retail customers within NSTAR Electric service territory without the written consent of NSTAR Electric.  This consent must be filed with the DPU and the municipality so affected. The franchises of NSTAR Electric include the power of eminent domain, obtained through application to the DPU.

The Massachusetts restructuring legislation defines service territories as those territories actually served on July 1, 1997 and following municipal boundaries to the extent possible.  The restructuring legislation further provides that until terminated by law or otherwise, distribution companies shall have the exclusive obligation to serve all retail customers within their service territories and no other person shall provide distribution service within such service territories without the written consent of such distribution companies.

PSNH  The NHPUC, pursuant to statutory requirements, has issued orders granting PSNH exclusive franchises to distribute electricity in the respective areas in which it is now supplying such service.

In addition to the right to distribute electricity as set forth above, the franchises of PSNH include, among others, rights and powers to manufacture, generate, purchase, and transmit electricity, to sell electricity at wholesale to other utility companies and municipalities and to erect and maintain certain facilities on certain public highways and grounds, all subject to such consents and approvals of public authority and others as may be required by law.  PSNH's status as a public utility gives it the ability to petition the NHPUC for the right to exercise eminent domain for distribution services and for transmission eligible for regional cost allocation.

PSNH is also subject to certain regulatory oversight by the Maine Public Utilities Commission and the Vermont Public Utility Commission.

NSTAR Gas Through its charter, which is unlimited in time, NSTAR Gas has the right to engage in the business of delivering and selling natural gas within its respective service territory, and has the power incidental thereto and is entitled to all the rights and privileges of and subject to the duties imposed upon natural gas companies under Massachusetts laws. The locations in public ways for natural gas distribution pipelines are obtained from municipal and other state authorities who, in granting these locations, act as agents for the state. In some cases, the actions of these authorities are subject to appeal to the DPU. The rights to these locations are not limited in time and are subject to the action of these authorities and the legislature. Under Massachusetts law, no other entity may provide natural gas delivery service to retail customers within the NSTAR Gas service territory without the written consent of NSTAR Gas. This consent must be filed with the DPU and the municipality so affected.

Yankee Gas  Yankee Gas holds valid franchises to sell natural gas in the areas in which Yankee Gas supplies natural gas service, which it acquired either directly or from its predecessors in interest.  Generally, Yankee Gas holds franchises to serve customers in areas designated by those franchises as well as in most other areas throughout Connecticut so long as those areas are not occupied and served by another natural gas utility under a valid franchise of its own or are not subject to an exclusive franchise of another natural gas utility or by consent.  Yankee Gas' franchises are perpetual but remain subject to the power of alteration, amendment or repeal by the General Assembly of the State of Connecticut, the power of revocation by the PURA and certain approvals, permits and consents of public authorities and others prescribed by statute.  Generally, Yankee Gas' franchises include, among other rights and powers, the right and power to manufacture, generate, purchase, transmit and distribute natural gas and to erect and maintain certain facilities on public highways and grounds, and the right of eminent domain, all subject to such consents and approvals of public authorities and others as may be required by law.

Aquarion Water Company of Connecticut AWC-CT derives its rights and franchises to operate from special acts of the Connecticut General Assembly and subject to certain approvals, permits and consents of public authority and others prescribed by statute and by its charter, AWC-CT has, with minor exceptions, solid franchises free from burdensome restrictions and unlimited as to time, and is authorized to sell potable water in the towns (or parts thereof) in which water is now being supplied by AWC-CT.

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In addition to the right to sell water as set forth above, the franchises of AWC-CT include rights and powers to erect and maintain certain facilities on public highways and grounds, all subject to such consents and approvals of public authority and others as may be required by law. Under the Connecticut General Statutes, AWC-CT may, upon payment of compensation, take and use such lands, springs, streams or ponds, or such rights or interests therein as the Connecticut Superior Court, upon application, may determine is necessary to enable AWC-CT to supply potable water for public or domestic use in its franchise areas.

Aquarion Water Company of Massachusetts Through its charters, which are unlimited in time, AWC-MA has the right to engage in the business of distributing and selling water within its service territories, and has the power incidental thereto and is entitled to all the rights and privileges of and subject to the duties imposed upon water companies under Massachusetts laws.  AWC-MA has the right to construct and maintain its mains and distribution pipes in and under any public ways and to take and hold water within its respective service territories. Subject to DPU regulation, AWC-MA has the right to establish and fix rates for use of the water distributed and to establish reasonable regulations regarding the same.  Certain of the towns within our service area have the right, at any time, to purchase the corporate property and all rights and privileges of AWC-MA according to pricing formulas and procedures specifically described in AWC-MA's respective charters and in compliance with Massachusetts law.

Aquarion Water Company of New Hampshire The NHPUC, pursuant to statutory law, has issued orders granting and affirming AWC-NH’s exclusive franchise to own, operate, and manage plant and equipment and any part of the same, for the conveyance of water for the public located within its franchise territory. That franchise territory encompasses the towns of Hampton, North Hampton and Rye. Subject to NHPUC’s regulations, AWC-NH has the right to establish and fix rates for use of the water distributed and to establish reasonable regulations regarding the same.

In addition to the right to provide water supply, the franchise also allows AWC-NH to sell water at wholesale to other water utilities and municipalities and to construct plant and equipment and maintain such plant and equipment on certain public highways and grounds, all subject to such consents and approvals of public authority and others as may be required by law.

AWC-NH's status as a regulated public utility gives it the ability to petition the NHPUC for the right to exercise eminent domain for the establishment of plant and equipment. It can also petition the NHPUC for exemption from the operation of any local ordinance when certain utility structures are reasonably necessary for the convenience or welfare of the public and the local conditions, and, if the purpose of the structure relates to water supply withdrawal, the exemption is recommended by the New Hampshire Department of Environmental Services.

Item 3.    Legal Proceedings

1.    Yankee Companies v. U.S. Department of Energy

The Yankee Companies have filed complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to accept delivery of, and provide for a permanent facility to store, spent nuclear fuel pursuant to the terms of the 1983 spent fuel and high-level waste disposal contracts between the Yankee Companies and the DOE. The court previously awarded the Yankee Companies damages for Phases I, II and III of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2012, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.

DOE Phase IV Damages - On May 22, 2017, each of the Yankee Companies filed a fourth set of lawsuits against the DOE in the Court of Federal

Claims. The Yankee Companies sought monetary damages totaling $104.4 million for CYAPC, YAEC and MYAPC, resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2013 to 2016 (“DOE Phase IV”). On February 21, 2019, the Yankee Companies received a partial summary judgment and partial final judgment in their favor for the undisputed amount of monetary damages of $103.2 million.  The court awarded CYAPC, YAEC, and MYAPC damages of $40.7 million, $28.1 million and $34.4 million, respectively. The DOE did not appeal the court's judgment and the decision became final on April 23, 2019. On June 12, 2019, each of the Yankee Companies received the damages proceeds. On June 12, 2019, the court accepted an offer of judgment in the amount of $0.5 million to settle the disputed amount of approximately $1 million in Phase IV contested damages. The Yankee Companies received the $0.5 million payment in July 2019. CYAPC's and YAEC's proceeds received were classified as operating activities on the Eversource consolidated statement of cash flows.

In September 2019, the Yankee Companies made a required informational filing with FERC as to the use of proceeds, for which approval was received in the fourth quarter of 2019. In December 2019, YAEC and MYAPC returned proceeds of $5.4 million and $21.0 million, respectively, to its member companies, of which the Eversource utilities (CL&P, NSTAR Electric and PSNH) received a total of $2.8 million from YAEC and $5.0 million from MYAPC. The Eversource utilities will ultimately refund these proceeds to utility customers. Also, in December 2019, CYAPC paid $29.0 million to the DOE to partially settle its pre-1983 spent nuclear fuel obligation.

2.    Other Legal Proceedings

For further discussion of legal proceedings, see Item 1, Business: "– Electric Distribution Segment," "– Electric Transmission Segment," and "– Natural Gas Distribution Segment" for information about various state and federal regulatory and rate proceedings, civil lawsuits related thereto, and information about proceedings relating to power, transmission and pricing issues; "– Nuclear Fuel Storage" for information related to nuclear waste; and "– Other Regulatory and Environmental Matters" for information about toxic substances and hazardous waste, electric and magnetic fields, and other matters. In addition, see Item 1A, Risk Factors, for general information about several significant risks.

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Item 4.    Mine Safety Disclosures

Not applicable.

PART II

Item 5.    Market for the Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

(a)    Market Information

Our common shares are listed on the New York Stock Exchange.  The ticker symbol is "ES."  There is no established public trading market for the common stock of CL&P, NSTAR Electric and PSNH.  All of the common stock of CL&P, NSTAR Electric and PSNH is held solely by Eversource.

(b)    Holders

As of January 31, 2020, there were 33,508 registered common shareholders of our company on record.  As of the same date, there were a total of 329,952,663 shares outstanding.

(c)     Dividends

Information with respect to dividends and dividend restrictions for Eversource, CL&P, NSTAR Electric and PSNH is contained in Item 8, Financial Statements and Supplementary Data, in the Combined Notes to Financial Statements, within this Annual Report on Form 10-K.   

(d)    Securities Authorized for Issuance Under Equity Compensation Plans

For information regarding securities authorized for issuance under equity compensation plans, see Item 12, Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters, included in this Annual Report on Form 10-K.

(e)    Performance Graph

The performance graph below illustrates a five-year comparison of cumulative total returns based on an initial investment of $100 in 2014 in Eversource Energy common stock, as compared with the S&P 500 Stock Index and the EEI Index for the period 2014 through 2019, assuming all dividends are reinvested.

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December 31,
	2014	2015	2016	2017	2018	2019
Eversource Energy	$100	$99	$110	$130	$138	$186
EEI Index	$100	$96	$113	$126	$131	$164
S&P 500	$100	$101	$114	$138	$132	$174

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

The following table discloses purchases of our common shares made by us or on our behalf for the periods shown below.  The common shares purchased consist of open market purchases made by the Company or an independent agent.  These share transactions related to matching contributions under the Eversource 401k Plan.

Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans and Programs (at month end)
October 1 - October 31, 2019	—	$	—	—	—
November 1 - November 30, 2019	20	82.94		—	—
December 1 - December 31, 2019	2,169	84.78		—	—
Total	2,189	$	84.76	—	—

Recent Sales of Unregistered Securities

In January 2020, we determined that during 2019 and early 2020, the Savings Plan for Employees of Aquarion Water Company, a 401(k) retirement plan (Plan), offered Eversource common shares (Shares) as an investment alternative for participants. The Plan trustee purchased Shares in the open market and allocated the Shares to participants’ Plan accounts at the election of participants.  During this period, the Plan sold 5,990 Shares to 35 participants, which Shares were not registered on Form S-8.  The investment alternative to purchase Shares under the Plan has been terminated, and we did not receive any proceeds from such sales, which were funded with participants' contributions to the Plan.

Item 6.    Selected Consolidated Financial Data

Eversource Selected Consolidated Financial Data (Unaudited)

(Thousands of Dollars, except percentages and   common share information)	2019		2018		2017		2016		2015
Balance Sheet Data:
Property, Plant and Equipment, Net	$	27,585,470	$	25,610,428	$	23,617,463	$	21,350,510	$	19,892,441
Total Assets	41,123,915		38,241,256		36,220,386		32,053,173		30,580,309
Common Shareholders' Equity	12,629,994		11,486,817		11,086,242		10,711,734		10,352,215
Noncontrolling Interest - Preferred Stock of Subsidiaries	155,570		155,570		155,570		155,568		155,568
Long-Term Debt (a)	14,098,239		13,086,062		12,325,520		9,603,237		9,034,457
Obligations Under Capital Leases (a)	10,516		10,735		9,898		8,924		8,222
Obligations Under Operating Leases (a)	49,966		—		—		—		—
Income Statement Data:
Operating Revenues	$	8,526,470	$	8,448,201	$	7,751,952	$	7,639,129	$	7,954,827
Net Income	$	916,572	$	1,040,519	$	995,515	$	949,821	$	886,004
Net Income Attributable to Noncontrolling Interests	7,519		7,519		7,519		7,519		7,519
Net Income Attributable to Common Shareholders	$	909,053	$	1,033,000	$	987,996	$	942,302	$	878,485
Common Share Data:
Net Income Attributable to Common Shareholders:
Basic Earnings Per Common Share	$	2.83	$	3.25	$	3.11	$	2.97	$	2.77
Diluted Earnings Per Common Share	$	2.81	$	3.25	$	3.11	$	2.96	$	2.76
Dividends Declared Per Common Share	$	2.14	$	2.02	$	1.90	$	1.78	$	1.67
Market Price - Closing (end of year) (b)	$	85.07	$	65.04	$	63.18	$	55.23	$	51.07
Book Value Per Common Share (end of year)	$	38.29	$	36.25	$	34.98	$	33.80	$	32.64
Tangible Book Value Per Common Share (end of year) (c)	$	24.86	$	22.27	$	21.00	$	22.70	$	21.54
Rate of Return Earned on Average Common Equity (%) (d)	7.5		9.2		9.1		9.0		8.7
Market-to-Book Ratio (end of year) (e)	2.2		1.8		1.8		1.6		1.6

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CL&P Selected Financial Data (Unaudited)
(Thousands of Dollars)	2019		2018		2017		2016		2015
Balance Sheet Data:
Property, Plant and Equipment, Net	$	9,625,765	$	8,909,701	$	8,271,030	$	7,632,392	$	7,156,809
Total Assets	12,185,191		11,409,719		10,630,246		10,035,044		9,592,957
Common Stockholder's Equity	4,387,825		4,199,317		3,587,127		3,470,387		3,140,717
Preferred Stock Not Subject to Mandatory Redemption	116,200		116,200		116,200		116,200		116,200
Long-Term Debt (a)	3,518,136		3,254,016		3,059,135		2,766,010		2,763,682
Obligations Under Finance Leases (a)	3,049		4,465		5,711		6,767		7,624
Obligations Under Operating Leases (a)	745		—		—		—		—
Income Statement Data:
Operating Revenues	3,232,551		3,096,174		2,887,359		2,805,955		2,802,675
Net Income	410,852		377,717		376,726		334,254		299,360
Common Stock Data:
Cash Dividends on Common Stock	341,800		60,000		254,800		199,599		196,000

^(a) Includes portions due within one year.

^(b) Market price information reflects closing prices as reflected by the New York Stock Exchange.  

^(c) Common Shareholders' Equity adjusted for goodwill and intangibles divided by total common shares outstanding.

^(d) Net Income Attributable to Common Shareholders divided by average Common Shareholders' Equity.  

^(e) The closing market price divided by the book value per share.

See the Combined Notes to Financial Statements in this Annual Report on Form 10-K for a description of the sale of PSNH's thermal and hydroelectric generation assets in 2018 and the December 31, 2017 classification of these generation assets as held for sale, the acquisition of Aquarion on December 4, 2017, and any accounting changes materially affecting the comparability of the information reflected in the tables above. As a result of the adoption of new accounting guidance on January 1, 2019, we recognized lease assets and liabilities for operating leases on the balance sheet. Prior period amounts were not adjusted and continue to be reported in accordance with our historic accounting policies.

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Item 7.    Management's Discussion and Analysis of Financial Condition and Results of Operations

EVERSOURCE ENERGY AND SUBSIDIARIES

The following discussion and analysis should be read in conjunction with our consolidated financial statements and related combined notes included in this combined Annual Report on Form 10-K.  References in this combined Annual Report on Form 10-K to "Eversource," the "Company," "we," "us," and "our" refer to Eversource Energy and its consolidated subsidiaries.  All per-share amounts are reported on a diluted basis.  The consolidated financial statements of Eversource, NSTAR Electric and PSNH and the financial statements of CL&P are herein collectively referred to as the "financial statements."  Our discussion of fiscal year 2019 compared to fiscal year 2018 is included herein. Unless expressly stated otherwise, for discussion and analysis of fiscal year 2017 items and fiscal year 2018 compared to fiscal year 2017, please refer to Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations, in our combined 2018 Annual Report on Form 10-K, which is incorporated herein by reference.

Refer to the Glossary of Terms included in this combined Annual Report on Form 10-K for abbreviations and acronyms used throughout this Management's Discussion and Analysis of Financial Condition and Results of Operations.  

The only common equity securities that are publicly traded are common shares of Eversource.  The earnings and EPS of each business discussed below do not represent a direct legal interest in the assets and liabilities of such business but rather represent a direct interest in our assets and liabilities as a whole.  EPS by business is a financial measure not recognized under GAAP, calculated by dividing the Net Income Attributable to Common Shareholders of each business by the weighted average diluted Eversource common shares outstanding for the period.  Our earnings discussion also includes a non-GAAP financial measure referencing our 2019 earnings and EPS excluding the impairment charge for the NPT project.

We use these non-GAAP financial measures to evaluate and provide details of earnings results by business and to more fully compare and explain our 2019 results without including the impact of the NPT impairment charge. We believe the NPT impairment charge is not indicative of our ongoing performance.  Due to the nature and significance of the impairment charge on Net Income Attributable to Common Shareholders, we believe that the non-GAAP presentation is a more meaningful representation of our financial performance and provides additional and useful information to readers of this report in analyzing historical and future performance of our business. These non-GAAP financial measures should not be considered as an alternative to reported Net Income Attributable to Common Shareholders or EPS determined in accordance with GAAP as an indicator of operating performance.

The results of Aquarion and its subsidiaries, hereinafter referred to as "Aquarion," are included from the date of the acquisition, December 4, 2017, through December 31, 2019 throughout this Management's Discussion and Analysis of Financial Condition and Results of Operations.

Financial Condition and Business Analysis

Executive Summary

The following items in this executive summary are explained in more detail in this combined Annual Report on Form 10-K:

Earnings Overview and Future Outlook:

• We earned $909.1 million, or $2.81 per share, in 2019, compared with $1.03 billion, or $3.25 per share, in 2018. Results for 2019 include an after-tax impairment charge of $204.4 million, or $0.64 per share, related to our investment in the NPT project. Excluding that impairment charge, we earned $1.11 billion, or $3.45 per share, in 2019.

• Our electric distribution segment earned $513.3 million, or $1.59 per share, in 2019, compared with $455.4 million, or $1.44 per share, in 2018.  Our electric transmission segment earned $256.5 million, or $0.79 per share, in 2019, compared with $427.2 million, or $1.34 per share, in 2018.  Excluding the after-tax NPT impairment charge of $204.4 million, or $0.64 per share, our electric transmission segment earned $460.9 million, or $1.43 per share, in 2019. Our natural gas distribution segment earned $96.2 million, or $0.30 per share, in 2019, compared with $93.2 million, or $0.29 per share, in 2018. Our water distribution segment earned $34.9 million, or $0.11 per share, in 2019, compared with $30.9 million, or $0.10 per share in 2018.

• Eversource parent and other companies earned $8.2 million, or $0.02 per share, in 2019, compared with $26.3 million, or $0.08 per share, in 2018.

• We currently project 2020 earnings of between $3.60 per share and $3.70 per share.

Liquidity:

• Cash flows provided by operating activities totaled $2.01 billion in 2019, compared with $1.83 billion in 2018.  Investments in property, plant and equipment totaled $2.91 billion in 2019 and $2.57 billion in 2018.  Cash totaled $15.4 million as of December 31, 2019, compared with $108.1 million as of December 31, 2018.  

• In 2019, we issued 11,980,000 common shares, which resulted in proceeds of $852.3 million, net of issuance costs.

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• In 2019, we issued $1.52 billion of new long-term debt, consisting of $500 million by CL&P, $400 million by NSTAR Electric, $300 million by PSNH, $200 million by Yankee Gas, $75 million by NSTAR Gas and $45 million by Aquarion.  Proceeds from these new issuances were used primarily to repay short-term borrowings, repay long-term debt at maturity and fund capital expenditures and working capital. In 2019, we repaid, at maturity, $801.1 million of previously issued long-term debt, consisting of $350 million by Eversource parent, $250 million by CL&P, $150 million by PSNH, $50 million by Yankee Gas and $1.1 million by Aquarion.  

• In 2019, we paid cash dividends of $663.2 million and issued non-cash dividends of $22.8 million in the form of treasury shares, totaling dividends of $2.14 per common share, compared with cash dividends of $640.1 million, or $2.02 per common share, in 2018.  On February 5, 2020, our Board of Trustees approved a common share dividend payment of $0.5675 per share, payable on March 31, 2020 to shareholders of record as of March 4, 2020.  The 2020 dividend represents an increase of 6.1 percent over the dividend paid in December 2019.

• We project to make capital expenditures of $14.19 billion from 2020 through 2024, of which we expect $8.63 billion to be in our electric and natural gas distribution segments, $3.98 billion to be in our electric transmission segment and $0.69 billion to be in our water distribution segment.  We also project to invest $0.90 billion in information technology and facilities upgrades and enhancements. These projections do not include any expected investments related to offshore wind projects. 

Strategic:

• On February 26, 2020, Eversource and NiSource entered into an asset purchase agreement where Eversource would acquire the assets that comprise NiSource’s local gas distribution business in Massachusetts for a purchase price of $1.1 billion. The liabilities to be assumed by Eversource specifically exclude any liabilities (past or future) arising out of or related to the fires and explosions that occurred on September 13, 2018 in Lawrence, Andover and North Andover, Massachusetts. The acquisition and resulting rate plan both require DPU and other approvals. Eversource and NiSource expect to close this transaction later this year.

Earnings Overview

Consolidated:  Below is a summary of our earnings by business, which also reconciles the non-GAAP financial measures of consolidated non-GAAP earnings and EPS, as well as EPS by business, to the most directly comparable GAAP measures of consolidated Net Income Attributable to Common Shareholders and diluted EPS.

	For the Years Ended December 31,
	2019						2018				2017
(Millions of Dollars, Except Per Share Amounts)	Amount			Per Share			Amount		Per Share		Amount		Per Share
Net Income Attributable to Common Shareholders (GAAP)	$	909.1		$	2.81		$	1,033.0	$	3.25	$	988.0	$	3.11
Regulated Companies	$	1,105.3		$	3.43		$	1,006.7	$	3.17	$	962.7	$	3.03
Eversource Parent and Other Companies	8.2			0.02			26.3		0.08		25.3		0.08
Non-GAAP Earnings	$	1,113.5		$	3.45		$	1,033.0	$	3.25	$	988.0	$	3.11
Impairment of Northern Pass Transmission (after-tax)	(204.4		)	(0.64		)	—		—		—		—
Net Income Attributable to Common Shareholders (GAAP)	$	909.1		$	2.81		$	1,033.0	$	3.25	$	988.0	$	3.11

Regulated Companies:  Our regulated companies comprise the electric distribution, electric transmission, natural gas distribution and water distribution segments. A summary of our segment earnings and EPS is as follows:

	For the Years Ended December 31,
	2019						2018				2017
(Millions of Dollars, Except Per Share Amounts)	Amount			Per Share			Amount		Per Share		Amount			Per Share
Net Income - Regulated Companies (GAAP)	$	900.9		$	2.79		$	1,006.7	$	3.17	$	962.7		$	3.03
Electric Distribution	$	513.3		$	1.59		$	455.4	$	1.44	$	497.4		$	1.57
Electric Transmission, excluding Northern Pass Transmission impairment (Non-GAAP)	460.9			1.43			427.2		1.34		391.9			1.23
Natural Gas Distribution	96.2			0.30			93.2		0.29		74.6			0.23
Water Distribution	34.9			0.11			30.9		0.10		(1.2		)	—
Net Income - Regulated Companies (Non-GAAP)	$	1,105.3		$	3.43		$	1,006.7	$	3.17	$	962.7		$	3.03
Impairment of Northern Pass Transmission (after-tax)	(204.4		)	(0.64		)	—		—		—			—
Net Income - Regulated Companies (GAAP)	$	900.9		$	2.79		$	1,006.7	$	3.17	$	962.7		$	3.03

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Our electric distribution segment earnings increased $57.9 million in 2019, as compared to 2018, due primarily to the CL&P, NSTAR Electric and PSNH base distribution rate increases, higher earnings from CL&P's capital tracker mechanism, effective July 1, 2018, due to increased electric system improvements, and higher earnings from NSTAR Electric's solar generation capital tracker mechanism. The earnings increase was partially offset by higher depreciation expense, lower non-service income from our benefit plans, higher operations and maintenance expense, the absence in 2019 of generation earnings at PSNH due to the sale of its generation assets in 2018, and the absence in 2019 of a gain on the sale of property at PSNH in 2018.

Our electric transmission segment earnings decreased $170.7 million in 2019, as compared to 2018, due primarily to the impairment of NPT, which resulted in an after-tax charge of $204.4 million, or $0.64 per share in 2019. Excluding the NPT impairment charge, earnings increased $33.7 million in 2019, as compared to 2018, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure and the absence in 2019 of approximately $6 million (after-tax) in tax-related regulatory assets that we concluded were not recoverable from customers in 2018. The earnings increase was partially offset by a lower benefit from the annual billing and cost reconciliation filing with FERC and the absence of the NPT AFUDC equity income.

Our natural gas distribution segment earnings increased $3.0 million in 2019, as compared to 2018, due primarily to the impact of the Yankee Gas base distribution rate increase effective November 15, 2018 and higher earnings from capital tracker mechanisms due to continued investments in natural gas infrastructure. The earnings increase was partially offset by higher operations and maintenance expense, higher depreciation expense, higher property and other tax expense, and higher interest expense.

Our water distribution segment earnings increased $4.0 million in 2019, as compared to 2018, due primarily to a lower effective tax rate driven by the elimination of a tax-related regulatory liability.

Eversource Parent and Other Companies:  Eversource parent and other companies earnings decreased $18.1 million in 2019, as compared to 2018, due primarily to a higher effective tax rate due in part to higher income tax reserves in 2019 and the absence in 2019 of income tax benefits recognized in 2018, higher interest expense, and the absence in 2019 of a 2018 benefit related to the allowed recovery of certain previously expensed merger-related costs in distribution rates. The earnings decrease was partially offset by the absence of the 2018 impairment of our investment in the Access Northeast project, and a higher return at Eversource Service as a result of increased investments in property, plant and equipment.

Liquidity

Cash totaled $15.4 million as of December 31, 2019, compared with $108.1 million as of December 31, 2018.

Short-Term Debt - Commercial Paper Programs and Credit Agreements: Eversource parent has a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas and Aquarion Water Company of Connecticut are also parties to a five-year $1.45 billion revolving credit facility. Effective December 9, 2019, the revolving credit facility's termination date was extended for one additional year to December 6, 2024. The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program.

NSTAR Electric has a $650 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. NSTAR Electric is also a party to a five-year $650 million revolving credit facility. Effective December 9, 2019, the revolving credit facility's termination date was extended for one additional year to December 6, 2024. The revolving credit facility serves to backstop NSTAR Electric's $650 million commercial paper program.

The amount of borrowings outstanding and available under the commercial paper programs were as follows:

	Borrowings Outstanding as of December 31,				Available Borrowing Capacity as of December 31,				Weighted-Average Interest Rate as of December 31,
(Millions of Dollars)	2019		2018		2019		2018		2019		2018
Eversource Parent Commercial Paper Program	$	1,224.9	$	631.5	$	225.1	$	818.5	1.98	%	2.77	%
NSTAR Electric Commercial Paper Program	10.5		278.5		639.5		371.5		1.63	%	2.50	%

There were no borrowings outstanding on either the Eversource parent or NSTAR Electric revolving credit facilities as of December 31, 2019 or 2018.

Amounts outstanding under the commercial paper programs and revolving credit facilities are included in Notes Payable and classified in current liabilities on the Eversource and NSTAR Electric balance sheets, as all borrowings are outstanding for no more than 364 days at one time.  As a result of the Eversource parent long-term debt issuance on January 10, 2020, the net proceeds of which were used to repay short-term borrowings outstanding under its commercial paper program, $346.3 million of commercial paper borrowings under the Eversource parent commercial paper program were classified as Long-Term Debt as of December 31, 2019.

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Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of December 31, 2019, there were intercompany loans from Eversource parent to CL&P of $63.8 million, to PSNH of $27.0 million, and to a subsidiary of NSTAR Electric of $30.3 million. As of December 31, 2018, there were intercompany loans from Eversource parent to PSNH of $57.0 million. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets.

Long-Term Debt: The following table summarizes long-term debt issuances and repayments:

(Millions of Dollars)	Issue Date	Issuance/(Repayment)			Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P:
4.00% 2018 Series A First Mortgage Bonds (1)	April 2019	$	300.0		April 2048	Paid short-term borrowings that were used to pay long-term debt that matured on February 1, 2019 and fund capital expenditures and working capital
3.20% 2017 Series A First Mortgage Bonds (2)	September 2019	200.0			March 2027	Paid short-term borrowings and fund capital expenditures and working capital
5.50% 2009 Series A First Mortgage Bonds	February 2009	(250.0		)	February 2019	Paid at maturity on February 1, 2019
NSTAR Electric:
3.25% 2019 Debentures	May 2019	400.0			May 2029	Paid short-term borrowings that were used to fund investments in eligible green expenditures
PSNH:
3.60% 2019 Series T First Mortgage Bonds	June 2019	300.0			July 2049	Paid long-term debt that matured in December 2019, paid short-term borrowings and fund capital expenditures and working capital
4.50% 2009 Series P First Mortgage Bonds	December 2009	(150.0		)	December 2019	Paid at maturity on December 1, 2019
Other:
Eversource Parent 4.50% Debentures	November 2009	(350.0		)	November 2019	Paid at maturity on November 15, 2019
Eversource Parent 3.45% Series P Senior Notes	January 2020	350.0			January 2050	Paid short-term borrowings
NSTAR Gas 3.74% Series Q First Mortgage Bonds	July 2019	75.0			August 2049	Paid short-term borrowings and fund capital expenditures and working capital
Yankee Gas 2.23% Series P First Mortgage Bonds	September 2019	100.0			October 2024	Paid short-term borrowings and for general corporate purposes
Yankee Gas 3.30% Series Q First Mortgage Bonds	September 2019	100.0			October 2049	Paid short-term borrowings and for general corporate purposes
Yankee Gas 5.26% Series H First Mortgage Bonds	November 2004	(50.0		)	November 2019	Paid at maturity on November 1, 2019
Aquarion 3.54% Senior Notes	December 2019	45.0			December 2049	Paid short-term borrowings

⁽¹⁾ These bonds are part of the same series issued by CL&P in March 2018. The aggregate outstanding principal amount of these bonds is now $800 million.

⁽²⁾ These bonds are part of the same series issued by CL&P in March 2017. The aggregate outstanding principal amount of these bonds is now $500 million.

Long-Term Debt Issuance Authorizations: On February 27, 2019, the DPU approved NSTAR Electric's request for authorization to issue up to $800 million in long-term debt through December 31, 2020. On April 26, 2019, the NHPUC approved PSNH's request for authorization to issue up to $300 million in long-term debt through December 31, 2019. On August 14, 2019, PURA approved CL&P's request for authorization to issue up to $675 million in long-term debt through December 31, 2022. On December 11, 2019, PURA approved Aquarion Water Company of Connecticut's request for authorization to issue up to $45 million of long-term debt. On January 27, 2020, the DPU approved NSTAR Gas' request for authorization to issue up to $270 million in long-term debt through December 31, 2021.

Rate Reduction Bonds: PSNH's RRB payments consist of principal and interest and are paid semi-annually, beginning on February 1, 2019. PSNH paid $52.3 million of RRB principal payments and $26.8 million of interest payments in 2019.

Common Share Issuance and Forward Sale Agreement: On June 4, 2019, Eversource completed an equity offering of 17,940,000 common shares, consisting of 5,980,000 common shares issued directly by the Company and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resulted in proceeds of $426.9 million, net of issuance costs.

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Under the forward sale agreement, a total of 11,960,000 common shares were borrowed from third parties and sold by the underwriters. The forward sale agreement allows Eversource, at its election and prior to May 29, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially, $71.48 per share) or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as dividends.

On December 30, 2019, Eversource physically settled a portion of the forward sale agreement by delivering 6,000,000 common shares in exchange for net proceeds of $425.4 million. The forward sale price used to determine the cash proceeds received by Eversource was calculated based on the initial forward sale price of $71.48 per share, as adjusted in accordance with the forward sale agreement.

The 2019 issuances of 11,980,000 common shares resulted in proceeds of $852.3 million, net of issuance costs, and were reflected in shareholders’ equity and as financing activities on the statement of cash flows.

Eversource’s intent is to physically settle the forward sale agreement by issuing common shares. As of December 31, 2019, if Eversource had elected to net settle the forward sale agreement, Eversource would have been required to pay $84.4 million under a cash settlement or would have been required to deliver 992,189 common shares under a net share settlement.

Issuances of shares under the forward sale agreement are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreement have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method. See Note 22, "Earnings Per Share," to the financial statements for information on the forward sale agreement’s impact on the calculation of diluted EPS.

Eversource used the net proceeds received upon the direct issuance of common shares and the net proceeds received upon partial settlement of the forward sale agreement to repay short-term debt under the commercial paper program, to fund capital spending and clean energy initiatives, and for general corporate purposes.

Cash Flows:  Cash flows provided by operating activities totaled $2.01 billion in 2019, compared with $1.83 billion in 2018.  The increase in operating cash flows was due primarily to a decrease in 2019 of approximately $148 million of major storm restoration cost payments, $116 million in lower payments made in 2019 to the DOE by CYAPC to partially settle its pre-1983 spent nuclear fuel obligation, and a $73.2 million decrease in pension and PBOP cash contributions made in 2019, as compared to 2018. Also contributing to the increase were $102.8 million of lower income tax payments made in 2019, as compared to 2018, $68.8 million in DOE Phase IV litigation proceeds received by CYAPC and YAEC in 2019, and the timing of cash collections on our accounts receivables. Partially offsetting these favorable impacts were the timing of collections for regulatory tracking mechanisms, which were significantly impacted by the timing of collections of purchased power and transmission costs at NSTAR Electric, and the timing of accounts payable cash payments and other working capital items.

Cash flows provided by operating activities totaled $1.83 billion in 2018, compared with $2.00 billion in 2017.  The decrease in operating cash flows was due primarily to cash payments made in 2018 for storm restoration costs of approximately $252 million, an increase of $128 million in income tax payments made in 2018, as compared to 2017, and the unfavorable impacts related to the timing of payments of our working capital items, including accounts receivable and accounts payable. In addition, in December 2018, CYAPC paid $145 million to the DOE to partially settle its pre-1983 spent nuclear fuel obligation. Partially offsetting these unfavorable impacts were the timing of cash collected for regulatory tracking mechanisms and a decrease of $47.9 million in 2018 of pension and PBOP contributions.

In 2019, we paid cash dividends of $663.2 million and issued non-cash dividends of $22.8 million in the form of treasury shares, totaling dividends of $2.14 per common share, compared with cash dividends of $640.1 million, or $2.02 per common share, in 2018. Our quarterly common share dividend payment was $0.535 per share in 2019, as compared to $0.505 per share in 2018.  On February 5, 2020, our Board of Trustees approved a common share dividend payment of $0.5675 per share, payable on March 31, 2020 to shareholders of record as of March 4, 2020.  The 2020 dividend represents an increase of 6.1 percent over the dividend paid in December 2019.

Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan.

In 2019, CL&P, NSTAR Electric and PSNH paid $341.8 million, $181.8 million and $271.0 million, respectively, in common stock dividends to Eversource parent.  

Investments in Property, Plant and Equipment on the statements of cash flows do not include amounts incurred on capital projects but not yet paid, cost of removal, AFUDC related to equity funds, and the capitalized and deferred portions of pension and PBOP expense.  In 2019, investments for Eversource, CL&P, NSTAR Electric and PSNH were $2.91 billion, $917.5 million, $861.4 million and $309.0 million, respectively.  

Eversource, CL&P, NSTAR Electric and PSNH each uses its available capital resources to fund its respective construction expenditures, meet debt requirements, pay operating costs, including storm-related costs, pay dividends, and fund other corporate obligations, such as pension contributions.  Eversource's regulated companies recover their electric, natural gas and water distribution construction expenditures as the related project costs are depreciated over the life of the assets.  This impacts the timing of the revenue stream designed to fully recover the total investment plus a return on the equity and debt used to finance the investments.  The current growth in Eversource's construction expenditures utilizes a significant amount of cash for projects that have a long-term return on investment and recovery period, totaling approximately $2.91 billion in cash capital spend in 2019.  In addition, Eversource's investments in its offshore wind business totaled $415.0 million in 2019, which are

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recognized as long-term assets. These factors have resulted in current liabilities exceeding current assets by $1.19 billion, $91.7 million, $280.5 million, and $36.7 million at Eversource, CL&P, NSTAR Electric and PSNH, respectively, as of December 31, 2019.

As of December 31, 2019, $296.1 million of Eversource's long-term debt, including $95.0 million, $50.0 million, $150.0 million, and $1.1 million for NSTAR Electric, Yankee Gas, NSTAR Gas and Aquarion, respectively, will mature within the next 12 months. Included in the current portion of long-term debt on the Eversource balance sheet is $31.3 million related to fair value adjustments from our various business combinations that will be amortized within the next 12 months and have no cash flow impact. Eversource, with its strong credit ratings, has several options available in the financial markets to repay or refinance these maturities with the issuance of new long-term debt.  Eversource, CL&P, NSTAR Electric and PSNH will reduce their short-term borrowings with operating cash flows or with the issuance of new long-term debt, determined by considering capital requirements and maintenance of Eversource's credit rating and profile.  

We expect the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with our existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.

Credit Ratings:  A summary of our corporate credit ratings and outlooks by Moody's, S&P and Fitch is as follows:

	Moody's		S&P		Fitch
	Current	Outlook	Current	Outlook	Current	Outlook
Eversource Parent	Baa1	Stable	A-	Stable	BBB+	Stable
CL&P	A3	Stable	A	Stable	A-	Stable
NSTAR Electric	A1	Stable	A	Stable	A	Stable
PSNH	A3	Stable	A	Stable	A-	Stable

A summary of the current credit ratings and outlooks by Moody's, S&P and Fitch for senior unsecured debt of Eversource parent and NSTAR Electric, and senior secured debt of CL&P and PSNH is as follows:

	Moody's		S&P		Fitch
	Current	Outlook	Current	Outlook	Current	Outlook
Eversource Parent	Baa1	Stable	BBB+	Stable	BBB+	Stable
CL&P	A1	Stable	A+	Stable	A+	Stable
NSTAR Electric	A1	Stable	A	Stable	A+	Stable
PSNH	A1	Stable	A+	Stable	A+	Stable

Business Development and Capital Expenditures

Our consolidated capital expenditures, including amounts incurred but not paid, cost of removal, AFUDC, and the capitalized and deferred portions of pension and PBOP expense (all of which are non-cash factors), totaled $3.06 billion in 2019, $2.86 billion in 2018, and $2.52 billion in 2017.  These amounts included $239.0 million in 2019, $184.6 million in 2018, and $165.9 million in 2017 related to information technology and facilities upgrades and enhancements, primarily at Eversource Service and The Rocky River Realty Company.

Electric Transmission Business: Our consolidated electric transmission business capital expenditures increased by $16.0 million in 2019, as compared to 2018.  A summary of electric transmission capital expenditures by company is as follows:  

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
CL&P	$	459.5	$	465.5	$	431.5
NSTAR Electric	379.7		334.3		301.9
PSNH	190.4		194.2		155.6
NPT	9.8		29.4		43.3
Total Electric Transmission Segment	$	1,039.4	$	1,023.4	$	932.3

Eastern Massachusetts Transmission Projects: These projects consist of a portfolio of electric transmission upgrades in southern New Hampshire, northern Massachusetts and continuing into the greater Boston metropolitan area, of which 28 upgrades are in Eversource's service territory (two in New Hampshire and 26 in Massachusetts). The two New Hampshire upgrades, including the Merrimack Valley Reliability Project, have been placed in service, and 20 Massachusetts upgrades have been placed in service. On December 17, 2019, the Massachusetts Siting Board issued a favorable decision on the Sudbury-Hudson Reliability Project, the last project requiring such approval. On January 17, 2020, the Town of Sudbury and Protect Sudbury, a community group, appealed the decision to the Massachusetts Supreme Judicial Court. The majority of the remaining upgrades are under construction and are expected to be placed in service in 2021.  We estimate our portion of the investment will be approximately $750 million, of which $442.2 million has been spent and capitalized through December 31, 2019.

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Hartford-Area Transmission Projects:  These projects consist of 27 projects in the Hartford, Connecticut area with an expected investment of approximately $350 million. As of December 31, 2019, 24 projects have been placed in service, and three projects are in active construction and are expected to be placed in service through mid-2020.  As of December 31, 2019, CL&P had spent and capitalized $275.9 million in costs associated with these projects.

Seacoast Reliability Project:  The Seacoast Reliability Project consists of a 13-mile, 115kV transmission line within several New Hampshire communities, using a combination of overhead, underground and underwater line designs to help meet the growing demand for electricity in the Seacoast region. On December 10, 2018, the NHSEC indicated its unanimous approval of the project, and subsequently issued its written decision on January 31, 2019. On May 13, 2019, two appeals of the NHSEC's approval orders were filed with the New Hampshire Supreme Court. On December 17, 2019, the Conservation Law Foundation requested the Court to withdraw its appeal, and the Court granted the request on December 20, 2019. The other appeal remains pending. This project is under construction and is scheduled to be completed in the second quarter of 2020. We estimate the investment will be approximately $125 million, of which PSNH had spent and capitalized $89.0 million in costs through December 31, 2019.

All project costs are anticipated to be fully recoverable through transmission rates.

Distribution Business:  A summary of distribution capital expenditures is as follows:

	For the Years Ended December 31,
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		Total Electric		Natural Gas		Water (1)		Total
2019
Basic Business	$	228.7	$	201.0	$	47.3	$	477.0	$	71.2	$	15.0	$	563.2
Aging Infrastructure	224.5		255.5		90.8		570.8		315.2		93.9		979.9
Load Growth and Other	59.6		89.4		16.8		165.8		66.8		1.5		234.1
Total Distribution	512.8		545.9		154.9		1,213.6		453.2		110.4		1,777.2
Solar	—		7.5		—		7.5		—		—		7.5
Total	$	512.8	$	553.4	$	154.9	$	1,221.1	$	453.2	110.4		$	1,784.7
2018
Basic Business	$	256.3	$	217.7	$	69.3	$	543.3	$	72.9	$	17.0	$	633.2
Aging Infrastructure	151.6		133.3		73.0		357.9		280.2		81.1		719.2
Load Growth and Other	79.7		94.3		15.6		189.6		51.4		3.6		244.6
Total Distribution	487.6		445.3		157.9		1,090.8		404.5		101.7		1,597.0
Solar and Other	—		53.4		0.9		54.3		—		—		54.3
Total	$	487.6	$	498.7	$	158.8	$	1,145.1	$	404.5	$	101.7	$	1,651.3
2017
Basic Business	$	214.0	$	166.1	$	67.2	$	447.3	$	67.7	N/A		$	515.0
Aging Infrastructure	180.7		95.4		87.8		363.9		219.9		N/A		583.8
Load Growth and Other	52.3		96.6		13.2		162.1		47.7		N/A		209.8
Total Distribution	447.0		358.1		168.2		973.3		335.3		N/A		1,308.6
Solar and Other	—		100.1		8.5		108.6		—		N/A		108.6
Total	$	447.0	$	458.2	$	176.7	$	1,081.9	$	335.3	N/A		$	1,417.2

⁽¹⁾  Our water distribution business was acquired on December 4, 2017. Amounts are immaterial for the year ended December 31, 2017.

For the electric distribution business, basic business includes the purchase of meters, tools, vehicles, information technology, transformer replacements, equipment facilities, and the relocation of plant.  Aging infrastructure relates to reliability and the replacement of overhead lines, plant substations, underground cable replacement, and equipment failures.  Load growth and other includes requests for new business and capacity additions on distribution lines and substation additions and expansions.

For the natural gas distribution business, basic business addresses daily operational needs including meters, pipe relocations due to public works projects, vehicles, and tools.  Aging infrastructure projects seek to improve the reliability of the system through enhancements related to cast iron and bare steel replacement of main and services, corrosion mediation, and station upgrades.  Load growth and other reflects growth in existing service territories including new developments, installation of services, and expansion.

For the water distribution business, basic business addresses daily operational needs including periodic meter replacement, water main relocation, facility maintenance, and tools. Aging infrastructure relates to reliability and the replacement of water mains, regulators, storage tanks, pumping stations, wellfields, reservoirs, and treatment facilities. Load growth and other reflects growth in our service territory, including improvements to acquisitions, installation of new services, and interconnections of systems.

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Acquisition of Assets of Columbia Gas of Massachusetts: On February 26, 2020, Eversource and NiSource entered into an asset purchase agreement (the Agreement) pursuant to which Eversource would acquire the assets that comprise NiSource’s local gas distribution business, currently doing business as Columbia Gas of Massachusetts (CMA). The purchase price of $1.1 billion includes a target working capital amount that would be adjusted to reflect actual working capital as of the closing date. Eversource would acquire approximately 330,000 residential, commercial, and industrial natural gas customers, as well as over 5,000 miles of natural gas distribution pipeline across more than 60 communities in Massachusetts.

The liabilities to be assumed by Eversource under the Agreement specifically exclude any liabilities (past and future) arising out of or related to the fires and explosions that occurred on September 13, 2018 in Lawrence, Andover and North Andover, Massachusetts related to the delivery of natural gas by CMA, including certain subsequent events, all as described in the DPU's Order on Scope dated December 23, 2019 (D.P.U. 19-141) (the Greater Lawrence Incident or GLI), and any further emergency events prior to the closing of the acquisition related to the restoration and reconstruction with respect to the GLI, including any losses arising out of or related to any litigation, demand, cause of action, claim, suit, investigation, proceeding, indemnification agreements or rights.

The acquisition and resulting rate plan both require DPU and other approvals. Eversource and NiSource expect to close this transaction later this year.

Projected Capital Expenditures:  A summary of the projected capital expenditures for the regulated companies' electric transmission and for the total electric distribution, natural gas distribution and water distribution for 2020 through 2024, including information technology and facilities upgrades and enhancements on behalf of the regulated companies, is as follows:

	Years
(Millions of Dollars)	2020		2021		2022		2023		2024		2020 - 2024 Total
CL&P Transmission	$	384	$	209	$	184	$	182	$	141	$	1,100
NSTAR Electric Transmission	366		478		436		296		284		1,860
PSNH Transmission	160		145		235		233		243		1,016
Total Electric Transmission	$	910	$	832	$	855	$	711	$	668	$	3,976
Electric Distribution	$	1,347	$	1,208	$	1,162	$	1,170	$	1,234	$	6,121
Natural Gas Distribution	470		498		501		507		537		2,513
Total Electric and Natural Gas Distribution	$	1,817	$	1,706	$	1,663	$	1,677	$	1,771	$	8,634
Water Distribution	$	124	$	127	$	134	$	147	$	153	$	685
Information Technology and All Other	$	220	$	169	$	165	$	171	$	171	$	896
Total	$	3,071	$	2,834	$	2,817	$	2,706	$	2,763	$	14,191

The projections do not include investments related to offshore wind projects.  Actual capital expenditures could vary from the projected amounts for the companies and years above.

Offshore Wind Business: Our offshore wind business includes ownership interests in North East Offshore and Bay State Wind, which together hold PPAs and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind projects, as well as offshore leases through BOEM. Our offshore wind projects are being developed and constructed through a joint and equal partnership with Ørsted. This partnership also participates in opportunities for solicitations for offshore wind energy in the Northeast U.S.

On February 8, 2019, Eversource and Ørsted entered into an equal partnership to acquire key offshore wind assets in the Northeast. Eversource has a 50 percent ownership interest in North East Offshore, which holds the Revolution Wind and South Fork Wind projects, as well as a 257 square-mile lease off the coasts of Massachusetts and Rhode Island. Eversource also has a 50 percent ownership interest in Bay State Wind, which holds the Sunrise Wind project. Bay State Wind's separate 300-square-mile ocean lease is located approximately 25 miles south of the coast of Massachusetts adjacent to the North East Offshore area. In aggregate, the Bay State Wind and the North East Offshore lease sites jointly-owned by Eversource and Ørsted could eventually develop at least 4,000 MW of clean, renewable offshore wind energy. As of December 31, 2019, Eversource's total equity investment balance in its offshore wind business was $649.3 million.

Currently we are developing our construction and operations plans, concluding on final offshore and onshore project designs and working through our siting and permitting processes, all of which is competitively sensitive. Subject to finalization of these plans, designs and processes, all of which are subject to change and modification as a result of our investment decisions, permit approval timelines and final design decisions, we currently expect to make additional investments in our offshore wind business of approximately $300 million to $400 million over the course of 2020.

The following table provides a summary of the Eversource and Ørsted major projects with announced contracts:

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Wind Project	State Servicing	Size (MW)	Term (Years)	Price per MWh	Pricing Terms	Projected In-Service Date	Contract Status
Revolution Wind	Rhode Island	400	20	$98.43	Fixed price contract; no price escalation	End of 2023	Approved
Revolution Wind	Connecticut	304	20	(1)	Fixed price contracts; no price escalation	End of 2023	Approved
South Fork Wind	New York (LIPA)	90	20	$160.33	2 percent average price escalation	End of 2022	Approved
South Fork Wind	New York (LIPA)	40	20	$86.25	2 percent average price escalation	End of 2022	(3)
Sunrise Wind	New York (NYSERDA)	880	25	$110.37 (2)	Fixed price contract; no price escalation	End of 2024	Approved

⁽¹⁾  The pricing for the Revolution Wind contracts in Connecticut has not yet been publicly disclosed.

⁽²⁾  Index OREC strike price.

⁽³⁾  The Long Island Power Authority (LIPA) agreed to expand the original 20-year PPA from 90 MW to 130 MW through an amendment to the original agreement. Negotiations are currently underway, and a final amendment is expected in the first half of 2020.

On October 23, 2019, the New York State Energy Research and Development Authority (NYSERDA) announced the execution of a 25-year agreement with the Sunrise Wind project to purchase Offshore Wind Renewable Energy Certificates (ORECs) from an 880 MW offshore wind facility. The Sunrise Wind project is held by Bay State Wind and will use a combination of lease areas from Bay State Wind and North East Offshore. Sunrise Wind will be developed 35 miles east of Montauk Point, Long Island.

The completion dates for these projects are subject to federal permitting through BOEM, engineering, state siting and permitting in New York and Rhode Island, and finalizing a PPA amendment in New York. Significant delays in the siting and permitting process, including the timing of obtaining BOEM approval, could adversely impact the timing of these projects' in-service dates. Currently, BOEM has indicated it will complete its Cumulative Impact Study as part of the Draft Supplemental Environmental Impact Statement (EIS) for a non-affiliated offshore wind project during the second quarter of 2020. The study is designed to assess the overall environmental impact of all offshore wind projects. Federal siting and permitting have commenced for the South Fork Wind project, as it has filed its Construction Operations Plan (COP) application with BOEM. South Fork Wind is designated as "FAST-41" by the U.S. Federal Permitting Improvement Council’s FAST-41 infrastructure projects, which provides greater federal assistance associated with program timelines. Revolution Wind and Sunrise Wind COP filings are planned in 2020.  South Fork Wind previously filed federal and state applications in 2018. State agencies also will review siting applications for Revolution Wind and Sunrise Wind in New York and Rhode Island, with application filings planned in 2020. 

FERC Regulatory Matters

FERC ROE Complaints: Four separate complaints were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively, the Complainants). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive (incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, the FERC set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the Court).

All amounts associated with the first complaint period have been refunded. Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of December 31, 2019. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of December 31, 2019.

On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.

The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.

If the results of the illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order.

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On November 21, 2019, FERC issued an order concerning the transmission ROEs for the Midcontinent ISO transmission owners (MISO). In that order, FERC adopted another new methodology for determining base ROEs for MISO, which differed significantly from the methodology and framework set forth in its October 16, 2018 FERC order on the NETOs’ ROE dockets. On December 23, 2019, the NETOs filed a Supplemental Paper Hearing Brief and a Motion to supplement the record in the NETO ROE dockets to respond to the new methodology proposed in the MISO order, as there is uncertainty to whether it may be applied to the NETOs’ cases. On January 21, 2020, the FERC issued an order granting rehearing for further consideration to give the FERC more time to act on the substantive issues of the MISO ROE proceedings. Further changes to the methodology by FERC are possible as a result of the arguments in both the MISO and NETO proceedings. Given the significant uncertainty relating to the October 2018 FERC order, the November 2019 FERC order to MISO, and the FERC's rehearing of the MISO order, the Company is unable to predict the potential effect of the MISO order on the NETO complaints or the outcome of the four complaints and concluded that there is no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods at this time. Further, the Company cannot reasonably estimate a range of gain or loss for any of the four complaint proceedings.

Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.

A change of 10 basis points to the base ROE used to establish the reserves would impact Eversource’s after-tax earnings by an average of approximately $3 million for each of the four 15-month complaint periods.

FERC Notices of Inquiry: On March 21, 2019, FERC issued two Notices of Inquiry (NOI) that may affect Eversource transmission ROEs and incentives. One NOI (the "FERC ROE NOI") seeks comments from all stakeholders on FERC's policies for evaluating ROEs for electric public utilities, and interstate natural gas and oil pipelines. The other NOI (the FERC transmission incentives NOI) seeks comments on FERC's policies for implementing electric transmission incentives. On June 26, 2019, the NETOs jointly filed comments in the FERC ROE NOI, supporting the methodology established in the FERC’s October 16, 2018 order with minor enhancements going forward. Also, on June 26, 2019, Eversource filed comments in the FERC transmission incentives NOI, requesting that FERC retain policies that have been effective in encouraging new transmission investment and remain flexible enough to attract investment in new and emerging transmission technologies. The NETOs jointly filed reply comments in the FERC ROE NOI on July 26, 2019.  Eversource filed reply comments in the FERC transmission incentives NOI on August 26, 2019. At this time, Eversource cannot predict how these NOIs will affect its ROEs or incentives.

FERC Transmission Rate Settlement: On December 28, 2015, FERC initiated a proceeding to review the NETOs' regional and local transmission formula rates due to a lack of transparency, finding that the formula rates appeared to lack sufficient details to determine how costs are derived and recovered in rates. This proceeding was set for hearing but held in abeyance to provide time for settlement judge procedures. On August 17, 2018, a signed Settlement Agreement between twenty-eight parties, including all six New England state regulatory commissions, the NETOs (including CL&P, NSTAR Electric and PSNH) and other settling parties, was filed at the FERC. The Settlement Agreement included, among other things, a new formula rate template in which all regional and local transmission revenue requirements will be determined through a single formula rate. The Settlement Agreement was contested by a group of municipal entities and the FERC Trial Staff. On May 22, 2019, FERC rejected the Settlement Agreement and remanded the proceeding for hearings. The parties have been engaged in further settlement negotiations and reached an agreement in principle on October 22, 2019.  The FERC Chief Administrative Law Judge has approved two suspensions of the schedule for ninety days each for the NETOs to review the terms with other active parties and finalize the settlement. The procedural schedule has been suspended to April 22, 2020.

U.S. Federal Corporate Income Taxes: Effective January 1, 2018, the local transmission service rates were updated to reflect the lower U.S. federal corporate income tax rate that resulted from the Tax Cuts and Jobs Act. On June 28, 2018, FERC granted a one-time waiver of tariff provisions related to the federal corporate income tax rate so that, effective June 1, 2018, the regional transmission service rates also reflect the reduced federal corporate income tax rate of 21 percent. The local and regional transmission service rates do not currently reflect amortization of excess ADIT (EDIT) balances that resulted from the Act. On November 15, 2018, FERC issued a Policy Statement and a separate Notice of Proposed Rulemaking addressing accounting and rate issues related to ADIT changes resulting from the Act. On November 21, 2019, FERC issued its final rule requiring public utilities with transmission formula rates to make adjustments to ADIT and EDIT. Eversource expects to submit a filing demonstrating its compliance with the final rule in the second half of 2020.

Regulatory Developments and Rate Matters

Electric, Natural Gas and Water Utility Base Distribution Rates:  Each Eversource utility subsidiary is subject to the regulatory jurisdiction of the state in which it operates:  CL&P, Yankee Gas and Aquarion operate in Connecticut and are subject to PURA regulation; NSTAR Electric, NSTAR Gas and Aquarion operate in Massachusetts and are subject to DPU regulation; and PSNH and Aquarion operate in New Hampshire and are subject to NHPUC regulation.  The regulated companies' distribution rates are set by their respective state regulatory commissions, and their tariffs include mechanisms for periodically adjusting their rates for the recovery of specific incurred costs.  

In Connecticut, electric and natural gas utilities are required to file a distribution rate case, or for PURA to initiate a rate review, within four years of the last rate case. CL&P's distribution rates were established in an April 2018 PURA-approved rate case settlement agreement with rates effective May 1, 2018. Yankee Gas' distribution rates were established in a December 2018 PURA-approved rate case settlement agreement with rates effective November 15, 2018. Aquarion is not required to initiate a rate review with the PURA. Aquarion rates were established in a 2013 PURA-approved rate case.

In Massachusetts, electric distribution companies are required to file at least one distribution rate case every five years, and natural gas local distribution companies to file at least one distribution rate case every 10 years, and those companies are limited to one settlement agreement in any 10-year period. NSTAR Electric's distribution rates were established in a 2017 DPU-approved rate case with rates effective February 1, 2018.

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NSTAR Gas' distribution rates were established in a 2015 DPU-approved rate case. See "Regulatory Developments and Rate Matters - Massachusetts" in this Management's Discussion and Analysis of Financial Condition and Results of Operations, for NSTAR Gas' November 2019 rate case application with the DPU. Aquarion is not required to initiate a rate review with the DPU. Aquarion rates were established in an October 2018 DPU-approved rate case.

In New Hampshire, PSNH's temporary distribution rates were established in a settlement agreement approved by the NHPUC on June 27, 2019, with temporary rates effective July 1, 2019. On May 28, 2019, PSNH filed an application with the NHPUC for a permanent increase in base distribution rates, effective July 1, 2020. See "Regulatory Developments and Rate Matters - New Hampshire" in this Management's Discussion and Analysis of Financial Condition and Results of Operations, for more information. Aquarion rates were established in a 2013 NHPUC-approved rate case, further revised in 2016. In a 2019 settlement approved by the NHPUC, Aquarion was ordered to file its next full rate proceeding no later than 2020.

Electric, Natural Gas and Water Utility Retail Rates: The Eversource electric distribution companies obtain and resell power to retail customers who choose not to buy energy from a competitive energy supplier.  The natural gas distribution companies procure natural gas for firm and seasonal customers.  These energy supply procurement costs are recovered from customers in energy supply rates that are approved by the respective state regulatory commission.  The rates are reset periodically and are fully reconciled to their costs.  Each electric and natural gas distribution company fully recovers its energy supply costs through approved regulatory rate mechanisms on a timely basis and, therefore, such costs have no impact on earnings.

The electric and natural gas distribution companies also recover certain other costs on a fully reconciling basis through regulatory commission-approved cost tracking mechanisms and, therefore, recovery of these costs have no impact on earnings.  Costs recovered through cost tracking mechanisms include, among others, energy efficiency program costs, electric retail transmission charges, electric restructuring and stranded costs (including securitized RRB charges), and additionally for our Massachusetts companies, pension and PBOP benefits and net metering for distributed generation.  The reconciliation filings compare the total actual costs allowed to revenue requirements related to these services and the difference between the costs incurred (or the rate recovery allowed) and the actual costs allowed is deferred and included, to be either recovered or refunded, in future customer rates.  These cost tracking mechanisms also include certain incentives earned, return on rate base, and carrying charges that are billed in rates to customers, which do impact earnings.

U.S. Federal Corporate Income Taxes: On December 22, 2017, the Tax Cuts and Jobs Act became law, which amended existing federal tax rules to reduce the U.S. federal corporate income tax rate from 35 percent to 21 percent effective January 1, 2018. For our regulated companies, the most significant changes are (1) the benefit of incurring a lower federal income tax expense and (2) the reduction in ADIT liabilities (now excess ADIT or EDIT), which are estimated to be approximately $2.8 billion and are included in regulatory liabilities as of December 31, 2019. The refund of these EDIT regulatory liabilities to customers will generally be made over the same period as the remaining useful lives of the underlying assets that gave rise to the ADIT liabilities. The refund of EDIT has begun at most of our distribution companies and is reflected in rates. The refund to customers and resulting amortization of the EDIT regulatory liabilities results in lower Revenues on the statements of income and lower current tax expense. This is offset by the reduction to Income Tax Expense due to the amortization of the EDIT. The refund of EDIT results in a lower effective tax rate and no impact on net income.

Eversource established a regulatory liability, recorded as a reduction to revenue, to reflect the difference between the 35 percent federal corporate income tax rate included in rates charged to customers and the 21 percent federal corporate income tax rate, effective January 1, 2018 as a result of the Tax Cuts and Jobs Act, until rates billed to customers reflected the lower federal tax rate. As of December 31, 2019, this liability, net of amounts refunded to customers, was $14.6 million.

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Eversource's regulated companies are in the process of, or will, refund the decrease in the income tax rate based on orders issued by applicable state and federal regulatory commissions. A summary of the timing of refunds related to the change in the tax rate is as follows:

Eversource Utility and Jurisdiction	EDIT Refund Timing	Effective Date of January 1, 2018 Tax Rate Reflected in Rates
Connecticut
CL&P	Reflected in rates effective May 1, 2019	May 1, 2018
Yankee Gas	Reflected in rates effective November 15, 2018	November 15, 2018
Massachusetts
NSTAR Electric	Reflected in rates effective January 1, 2019	February 1, 2018
NSTAR Gas	Reflected in rates effective February 1, 2019	July 1, 2018
New Hampshire
PSNH	Refunds for EDIT are being addressed in permanent distribution rate case filing Refunds for EDIT related to PSNH's divested generation assets reflected in rates effective August 1, 2018	July 1, 2019 for distribution
Transmission
CL&P, NSTAR Electric and PSNH	Refunds for EDIT will be made based on November 2019 final ruling from FERC. Eversource expects to submit a filing demonstrating its compliance with the final rule in the second half of 2020.	January 1, 2018 for local transmission service and June 1, 2018 for regional transmission service

Connecticut:

CL&P Storm Filing: CL&P's approved rate case settlement in 2018 incorporated $18.6 million of rate base recovery for catastrophic storms occurring after December 31, 2016, subject to a future storm filing.  On November 16, 2018, CL&P filed for recovery of $153 million of storm costs incurred from October 2017 through May 2018, with recovery over six years to begin May 1, 2019.  Through the course of the proceeding, CL&P updated its request to $145.5 million to reflect final invoicing and capitalization amounts. On April 17, 2019, PURA authorized recovery of $141.0 million as part of storm cost recovery and the remainder to be recorded to plant or other balance sheet accounts.

Massachusetts:

NSTAR Electric Distribution Rates: As part of an inflation-based mechanism, NSTAR Electric submitted its second annual Performance Based Rate Adjustment filing on September 16, 2019 and the DPU approved a $33.6 million increase to base distribution rates on December 19, 2019 for effect on January 1, 2020.

NSTAR Gas Rate Case: On November 8, 2019, NSTAR Gas filed its application with the DPU, which sought a distribution rate increase of $38.0 million effective October 1, 2020. As part of this filing, NSTAR Gas also proposed to continue its ongoing Gas System Enhancement Program (GSEP), include the GSEP investments since 2015 into base rates, and implement a performance-based ratemaking plan. A final decision from the DPU is expected by September 30, 2020.

Hingham Vote to Acquire Water System: On April 22, 2019, the town of Hingham, Massachusetts voted to acquire the water system and treatment plant that supplies water to the towns of Hingham, Hull and North Cohasset.  The acquisition price is currently estimated to be more than $100 million, subject to adjustment based on actual capital investments as legally required and other future closing adjustments.  Aquarion will continue to operate the water system consistent in all material respects with its obligations under applicable law during the transition period, until the sale closes.  The Company is evaluating the impact of the sale on its financial statements, which will be recorded when the sale transaction closes.  No loss is expected upon the ultimate conclusion of this transaction. The transaction is expected to close in the second half of 2020. As of December 31, 2019, these water distribution assets were included within Property, Plant and Equipment, Net and goodwill on the balance sheet and were also reflected in the Water Distribution segment and reporting unit.

New Hampshire:

Distribution Rates: On April 26, 2019, PSNH filed an application with the NHPUC for approval of a temporary annual base distribution rate increase of approximately $33 million, effective July 1, 2019. On June 27, 2019, the NHPUC approved a settlement agreement that was reached by PSNH, the NHPUC Staff, the Office of the Consumer Advocate, and another settling party, to implement a temporary annual base distribution rate increase of $28.3 million. Although new rates were implemented on August 1, 2019 to customers, the provisions of the temporary base distribution rate increase were effective July 1, 2019. The settlement agreement also permits PSNH to recover approximately $68.5 million in unrecovered storm costs over a five-year period beginning August 1, 2019, with debt carrying charges, which is included in the temporary rate increase.

On May 28, 2019, PSNH filed an application with the NHPUC for a permanent increase in base distribution rates of approximately $70 million, effective July 1, 2020, which includes the temporary rate increase request.  The temporary rates are subject to reconciliation based on the outcome of the permanent rate case now before the NHPUC. The NHPUC is permitted up to twelve months to adjudicate the permanent rate application from the date of filing. A decision by the NHPUC is expected in the second quarter of 2020.

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2013 through 2016 Storm Costs: On March 26, 2019, the NHPUC approved the recovery of $38.1 million, plus carrying charges, of storm costs incurred from December 2013 through April 2016 and the transfer of funding from PSNH’s major storm reserve to recover those costs. The costs of these storms (excluding the equity return component of the carrying charges) were deferred as regulatory assets, and the funding reserve collected from customers was accrued as a regulatory liability. As a result of the duration of time between incurring storm costs in December 2013 through April 2016 and final approval from the NHPUC in 2019, PSNH recognized $5.2 million (pre-tax) for the equity return component of the carrying charges within Other Income, Net on the statement of income in 2019, which has been collected from customers. Also included in the March 26, 2019 NHPUC approval is a prospective requirement for PSNH to annually net its storm funding reserve collected from customers against deferred storm costs.

Legislative and Policy Matters

New Hampshire: On July 8, 2019, the New Hampshire Superior Court approved a settlement between PSNH and the Town of Bow, New Hampshire, where the town had over-assessed the value of the property owned by PSNH for the 2014 through 2018 property tax years. The result of this settlement was $10.0 million in over-paid property taxes, of which PSNH has received $4.25 million in cash through December 31, 2019. PSNH will receive the balance thereafter to be credited against future property taxes payable, annually through 2023.

In addition, PSNH reached a collective resolution with an additional 61 municipalities for an aggregate total of approximately $7 million, where the towns had over-assessed the value of the property owned by PSNH for the 2015 through 2017 property tax years.

Federal: On December 20, 2019, the "Further Consolidated Appropriations Act, 2020," became law, which provided a one-year extension of the production tax credit or the investment tax credit for renewable wind projects under Section 45 of the Internal Revenue Code of 1986 on which construction begins before January 1, 2021. If construction begins on a qualifying wind project in 2020, the project will qualify for a production tax credit of $15 per MWh or an 18 percent investment tax credit. 

Critical Accounting Policies

The preparation of financial statements in conformity with GAAP requires management to make estimates, assumptions and, at times, difficult, subjective or complex judgments.  Changes in these estimates, assumptions and judgments, in and of themselves, could materially impact our financial position, results of operations or cash flows.  Our management discusses with the Audit Committee of our Board of Trustees significant matters relating to critical accounting policies.  Our critical accounting policies are discussed below.  See the combined notes to our financial statements for further information concerning the accounting policies, estimates and assumptions used in the preparation of our financial statements.  

Regulatory Accounting:  Our regulated companies are subject to rate regulation that is based on cost recovery and meets the criteria for application of accounting guidance for rate-regulated operations, which considers the effect of regulation on the timing of the recognition of certain revenues and expenses.  The regulated companies' financial statements reflect the effects of the rate-making process.  The rates charged to the customers of our regulated companies are designed to collect each company's costs to provide service, plus a return on investment.  

The application of accounting guidance for rate-regulated enterprises results in recording regulatory assets and liabilities.  Regulatory assets represent the deferral of incurred costs that are probable of future recovery in customer rates.  Regulatory assets are amortized as the incurred costs are recovered through customer rates.  In some cases, we record regulatory assets before approval for recovery has been received from the applicable regulatory commission.  We must use judgment to conclude that costs deferred as regulatory assets are probable of future recovery.  We base our conclusion on certain factors, including, but not limited to, regulatory precedent.  Regulatory liabilities represent either revenues received from customers to fund expected costs that have not yet been incurred or probable future refunds to customers.

We use judgment when recording regulatory assets and liabilities; however, regulatory commissions can reach different conclusions about the recovery of costs, and those conclusions could have a material impact on our financial statements.  We believe it is probable that each of the regulated companies will recover the regulatory assets that have been recorded.  If we determine that we can no longer apply the accounting guidance applicable to rate-regulated enterprises to our operations, or that we cannot conclude it is probable that costs will be recovered from customers in future rates, the costs would be charged to net income in the period in which the determination is made.

Pension, SERP and PBOP:  We sponsor Pension, SERP and PBOP Plans to provide retirement benefits to our employees.  For each of these plans, several significant assumptions are used to determine the projected benefit obligation, funded status and net periodic benefit cost.  These assumptions include the expected long-term rate of return on plan assets, discount rate, compensation/progression rate and mortality and retirement assumptions.  We evaluate these assumptions at least annually and adjust them as necessary.  Changes in these assumptions could have a material impact on our financial position, results of operations or cash flows.  

Expected Long-Term Rate of Return on Plan Assets:  In developing the expected long-term rate of return, we consider historical and expected returns, as well as input from our consultants.  Our expected long-term rate of return on assets is based on assumptions regarding target asset allocations and corresponding expected rates of return for each asset class.  We routinely review the actual asset allocations and periodically rebalance the investments to the targeted asset allocations when appropriate.  For the year ended December 31, 2019, our expected long-term rate-of-return assumption used to determine our pension and PBOP expense was 8.25 percent for the Eversource Service plans and 7 percent for the Aquarion plans.  For the forecasted 2020 pension and PBOP expense, an expected long-term rate of return of 8.25 percent for the Eversource Service plans and 7 percent for the Aquarion plans will be used reflecting our target asset allocations.

Discount Rate:  Payment obligations related to the Pension, SERP and PBOP Plans are discounted at interest rates applicable to the expected timing of each plan's cash flows.  The discount rate that was utilized in determining the pension, SERP and PBOP obligations was based on a yield-curve approach.  This approach utilizes a population of bonds with an average rating of AA based on bond ratings by Moody's, S&P and Fitch, and uses bonds with above median yields within that population.  As of December 31, 2019, the discount rates used to determine the funded status were within a range of 3.04 percent to 3.35 percent for the Pension and SERP Plans, and within a range of 3.26 percent to 3.28 percent for the PBOP Plans.  As of December 31, 2018, the discount rates used were within a range of 4.22 percent to 4.45 percent for the Pension and SERP Plans, and within a range of 4.38 percent to 4.41 percent for the PBOP Plans.  The decrease in the discount rates used to calculate the funded status resulted in an increase to the Pension and PBOP Plans' liability of $813.1 million and $88.6 million, respectively, as of December 31, 2019.  

The Company uses the spot rate methodology for the service and interest cost components of Pension, SERP and PBOP expense because it provides a more precise measurement by matching projected cash flows to the corresponding spot rates on the yield curve.  The discount rates used to estimate the 2019 expense were within a range of 2.63 percent to 3.55 percent for the Pension and SERP Plans, and within a range of 3.85 percent to 4.65 percent for the PBOP Plans.  

Mortality Assumptions:  Assumptions as to mortality of the participants in our Pension, SERP and PBOP Plans are a key estimate in measuring the expected payments a participant may receive over their lifetime and the corresponding plan liability we need to record. In 2019, a revised scale for the mortality table was released, and we utilized it in our measurements.

Compensation/Progression Rate:  This assumption reflects the expected long-term salary growth rate, including consideration of the levels of increases built into collective bargaining agreements, and impacts the estimated benefits that Pension and SERP Plan participants receive in the future.  As of December 31, 2019 and 2018, the compensation/progression rate used to determine the funded status was 3.50 percent for the Eversource Service plans and 4 percent for the Aquarion plans.  

Health Care Cost: The Eversource Service PBOP Plan is not subject to health care cost trends. As of December 31, 2019, for the Aquarion PBOP Plan, the health care cost trend rate is a range of 3.5 percent to 6.5 percent, with an ultimate rate of 3.5 percent to 5 percent in 2019 and 2023, for post-65 and pre-65 retirees, respectively.

Actuarial Determination of Expense:  Pension, SERP and PBOP expense is determined by our actuaries and consists of service cost and prior service cost, interest cost based on the discounting of the obligations, and amortization of actuarial gains and losses, offset by the expected return on plan assets. Actuarial gains and losses represent the amortization of differences between assumptions and actual information or updated assumptions. Pre-tax net periodic benefit expense for the Pension and SERP Plans was $63.7 million, $39.6 million and $64.9 million for the years ended December 31, 2019, 2018 and 2017, respectively.  For the PBOP Plans, there was net periodic PBOP income of $41.5 million, $45.0 million and $39.6 million for the years ended December 31, 2019, 2018 and 2017, respectively.  

The expected return on plan assets is determined by applying the assumed long-term rate of return to the Pension and PBOP Plan asset balances. This calculated expected return is compared to the actual return or loss on plan assets at the end of each year to determine the investment gains or losses to be immediately reflected in unamortized actuarial gains and losses.  

Forecasted Expenses and Expected Contributions:  We estimate that expense in 2020 for the Pension and SERP Plans will be approximately $53 million and income in 2020 for the PBOP Plans will be approximately $52 million. Pension, SERP and PBOP expense for subsequent years will depend on future investment performance, changes in future discount rates and other assumptions, and various other factors related to the populations participating in the plans.

Our policy is to fund the Pension Plans annually in an amount at least equal to the amount that will satisfy all federal funding requirements.  We contributed $112.5 million to the Pension Plans in 2019.  We currently estimate contributing $105.0 million to the Pension Plans in 2020.  

It is our policy to fund the PBOP Plans annually through tax deductible contributions to external trusts.  We contributed $9.3 million to the PBOP Plans in 2019.  We currently estimate contributing $2.9 million to the PBOP Plans in 2020.

Sensitivity Analysis:  The following represents the hypothetical increase to the Pension Plans' (excluding the SERP Plans) reported annual cost and a decrease to the PBOP Plans' reported annual income as a result of a change in the following assumptions by 50 basis points:

(Millions of Dollars)	Increase in Pension Plan Cost				Decrease in PBOP Plan Income
Assumption Change	As of December 31,				As of December 31,
Eversource	2019		2018		2019		2018
Lower expected long-term rate of return	$	22.9	$	23.7	$	4.1	$	4.5
Lower discount rate	21.7		25.5		1.7		2.9
Higher compensation rate	8.7		6.8		N/A		N/A

Goodwill:  We recorded goodwill on our balance sheet associated with previous mergers and acquisitions, which totaled $4.4 billion as of December 31, 2019. We have identified our reporting units for purposes of allocating and testing goodwill as Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution.  Electric Distribution and Electric Transmission reporting units include carrying values for the respective components of CL&P, NSTAR Electric and PSNH.  The Natural Gas Distribution reporting unit includes the carrying values of NSTAR Gas and Yankee Gas. The Water Distribution reporting unit includes the Aquarion water utility businesses.  As of December 31, 2019, goodwill was allocated to the reporting units as follows:  $2.5 billion to Electric Distribution, $0.6 billion to Electric Transmission, $0.4 billion to Natural Gas Distribution and $0.9 billion to Water Distribution.

We are required to test goodwill balances for impairment at least annually by considering the fair values of the reporting units, which requires us to use estimates and judgments.  We have selected October 1st of each year as the annual goodwill impairment testing date.  Goodwill impairment is deemed to exist if the carrying amount of a reporting unit exceeds its estimated fair value and if the implied fair value of goodwill based on the estimated fair values of the reporting units' assets and liabilities is less than the carrying amount of the goodwill.  If goodwill were deemed to be impaired, it would be written down in the current period to the extent of the impairment.  

We performed an impairment test of goodwill as of October 1, 2019 for the Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reporting units.  This evaluation required the consideration of several factors that impact the fair value of the reporting units, including conditions and assumptions that affect the future cash flows of the reporting units. Key considerations include discount rates, utility sector market performance and merger transaction multiples, and internal estimates of future cash flows and net income.  

The 2019 goodwill impairment test resulted in a conclusion that goodwill is not impaired and no reporting unit is at risk of a goodwill impairment. The fair value of the reporting units was substantially in excess of carrying value.

Long-Lived Assets: Impairment evaluations of long-lived assets, including property, plant and equipment and other assets, involve a significant degree of estimation and judgment, including identifying circumstances that indicate an impairment may exist. Impairment analysis is required when events or changes in circumstances indicate that the carrying value of a long-lived asset may not be recoverable. Indicators of potential impairment include a deteriorating business climate, unfavorable regulatory action, decline in value that is other than temporary in nature, plans to dispose of a long-lived asset significantly before the end of its useful life, and accumulation of costs that are in excess of amounts allowed for recovery. The review of long-lived assets for impairment utilizes significant assumptions about operating strategies and external developments, including assessment of current and projected market conditions that can impact future cash flows.

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Impairment of Northern Pass Transmission:  Northern Pass was Eversource's planned 1,090 MW HVDC transmission line that would have interconnected from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire.  As a result of a final decision received on July 19, 2019 from the New Hampshire Supreme Court, whereby the court denied Northern Pass’ appeal and affirmed the NHSEC’s denial of Northern Pass’ siting application on NPT, Eversource concluded that construction of NPT was no longer probable and that there was no constructive path forward for the project. Eversource terminated the project and permanently abandoned any further development.  As a result, substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired.

Based on the conclusion that the construction of Northern Pass was no longer probable, Eversource recorded an impairment charge in 2019 for all of the project costs associated with Northern Pass, which were primarily engineering design, siting, permitting and legal costs, along with appropriate allowances for funds used during construction, and recognized a receivable for certain cost reimbursement agreements. Additionally, Eversource recorded an impairment charge associated with the land acquired to construct Northern Pass in order to recognize the land at its estimated fair value based on assessed values and transaction costs. In total, this resulted in a pre-tax impairment charge of $239.6 million within Operating Income on the statement of income for the year ended December 31, 2019, and was reflected in the Electric Transmission segment. The after-tax impact of the impairment charge was $204.4 million, or $0.64 per share, after giving effect to the estimated fair value of the related land, reimbursement agreements, and the impact of expected income tax benefits associated with the impairment charge. As a result of the decision to terminate the NPT project and permanently abandon any further development, Eversource does not expect any future cash expenditures associated with this project.

Equity Method Investments: Investments in affiliates where we have the ability to exercise significant influence, but not control, over an investee are initially recognized as an equity method investment at cost. Any differences between the cost of an investment and the amount of underlying equity in net assets of an investee are considered basis differences, and are determined based upon the estimated fair values of the investee's identifiable assets and liabilities. For our offshore wind equity method investment, basis differences are related to intangible assets for PPAs that will be amortized over the term of the PPAs, and equity method goodwill that are not amortized. Capitalized interest associated with our offshore wind equity method investment is included in the investment balance.

Equity method investments are assessed for impairment when conditions exist that indicate that the fair value of the investment is less than book value.  If the decline in value is considered to be other-than-temporary, the investment is written down to its estimated fair value, which establishes a new cost basis in the investment. Impairment evaluations involve a significant degree of judgment and estimation, including identifying circumstances that indicate an impairment may exist and developing an estimate of undiscounted future cash flows.

Eversource recorded an other-than-temporary impairment of $32.9 million within Other Income, Net on our statement of income in 2018, related to Access Northeast, an equity method investment. In September 2018, a series of non-Eversource natural gas explosions in eastern Massachusetts resulted in widespread property and system damage, personal injuries, and a fatality. Eversource identified the September 2018 natural gas series of explosions, compounded by the adverse legislative environment, as negative evidence that indicated potential impairment of our investment in Access Northeast. Our impairment assessment used a discounted cash flow approach, including consideration of the severity and duration of any decline in fair value of our investment in the project, and involved significant management judgment and estimation, including projections of the project’s discounted cash flows and assumptions about exit price. In the third quarter of 2018, management determined that the future cash flows of the Access Northeast project were uncertain and could no longer be reasonably estimated and that the book value of our equity method investment was not recoverable. On April 1, 2019, pursuant to a provision in the partnership agreement jointly entered into by Eversource, Enbridge, Inc. and National Grid plc, through Algonquin Gas Transmission, LLC, the Access Northeast project was terminated.

Income Taxes: Income tax expense is estimated for each of the jurisdictions in which we operate and is recorded each quarter using an estimated annualized effective tax rate.  This process to record income tax expense involves estimating current and deferred income tax expense or benefit and the impact of temporary differences resulting from differing treatment of items for financial reporting and income tax return reporting purposes.  Such differences are the result of timing of the deduction for expenses, as well as any impact of permanent differences, non-tax deductible expenses, or other items that directly impact income tax expense as a result of regulatory activity (flow-through items).  The temporary differences and flow-through items result in deferred tax assets and liabilities that are included in the balance sheets.

We also account for uncertainty in income taxes, which applies to all income tax positions previously filed in a tax return and income tax positions expected to be taken in a future tax return that have been reflected on our balance sheets.  The determination of whether a tax position meets the recognition threshold under applicable accounting guidance is based on facts and circumstances available to us.  

On December 22, 2017, the Tax Cuts and Jobs Act became law, which amended existing federal tax rules and included numerous provisions that impacted corporations.  In particular, the act reduced the U.S. federal corporate income tax rate from 35 percent to 21 percent effective January 1, 2018.  For our regulated companies, the most significant changes are (1) the benefit of incurring a lower federal income tax expense and (2) the reduction in ADIT liabilities (now excess ADIT or EDIT), which are estimated to be approximately $2.8 billion and are included in regulatory liabilities as of December 31, 2019. Eversource's regulated companies are in the process of, or will be, refunding the EDIT liabilities to customers based on orders issued by applicable state regulatory commissions. The refund of these regulatory liabilities to customers will generally be made over the same period as the remaining useful lives of the underlying assets that gave rise to the ADIT liabilities.

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Accounting for Environmental Reserves:  Environmental reserves are accrued when assessments indicate it is probable that a liability has been incurred and an amount can be reasonably estimated. Increases to estimates of environmental liabilities could have an adverse impact on earnings. We estimate these liabilities based on findings through various phases of the assessment, considering the most likely action plan from a variety of available remediation options (ranging from no action required to full site remediation and long-term monitoring), current site information from our site assessments, remediation estimates from third party engineering and remediation contractors, and our prior experience in remediating contaminated sites.  If a most likely action plan cannot yet be determined, we estimate the liability based on the low end of a range of possible action plans. A significant portion of our environmental sites and reserve amounts relate to former MGP sites that were operated several decades ago and manufactured natural gas from coal and other processes, which resulted in certain by-products remaining in the environment that may pose a potential risk to human health and the environment, for which we may have potential liability.  Estimates are based on the expected remediation plan. Our estimates are subject to revision in future periods based on actual costs or new information from other sources, including the level of contamination at the site, the extent of our responsibility or the extent of remediation required, recently enacted laws and regulations or a change in cost estimates due to certain economic factors.  

Fair Value Measurements:  We follow fair value measurement guidance that defines fair value as the price that would be received for the sale of an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price).  We have applied this guidance to our Company's derivative contracts that are not elected or designated as "normal purchases or normal sales" (normal), to marketable securities held in trusts, and to our investments in our Pension and PBOP Plans. Fair value measurements are also incorporated into the accounting for goodwill, long-lived assets and AROs. We also applied this guidance in the valuation of our basis differences in our equity method offshore wind investments. The fair value measurement guidance was also applied in estimating the fair value of preferred stock, long-term debt and RRBs.

Changes in fair value of the derivative contracts are recorded as Regulatory Assets or Liabilities, as we recover the costs of these contracts in rates charged to customers.  These valuations are sensitive to the prices of energy and energy-related products in future years for which markets have not yet developed and assumptions are made.  

We use quoted market prices when available to determine the fair value of financial instruments.  If quoted market prices are not available, fair value is determined using quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments that are not active and model-derived valuations.  When quoted prices in active markets for the same or similar instruments are not available, we value derivative contracts using models that incorporate both observable and unobservable inputs.  Significant unobservable inputs utilized in the models include energy and energy-related product prices for future years for long-dated derivative contracts and market volatilities.  Discounted cash flow valuations incorporate estimates of premiums or discounts, reflecting risk-adjusted profit that would be required by a market participant to arrive at an exit price, using available historical market transaction information.  Valuations of derivative contracts also reflect our estimates of nonperformance risk, including credit risk.

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Other Matters

Accounting Standards:  For information regarding new accounting standards, see Note 1C, "Summary of Significant Accounting Policies - Accounting Standards," to the financial statements.

Contractual Obligations and Commercial Commitments:  Information regarding our contractual obligations and commercial commitments as of December 31, 2019, is summarized annually through 2024 and thereafter as follows:

Eversource
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Long-term debt maturities (a)	$	296.1	$	1,033.6	$	1,188.9	$	1,665.2	$	1,049.8	$	8,447.8	$	13,681.4
Rate reduction bond maturities	43.2		43.2		43.2		43.2		43.2		367.3		583.3
Estimated interest payments on existing debt (b)	511.5		493.4		458.4		425.5		384.1		4,020.3		6,293.2
Operating leases (c)	10.2		9.0		7.4		4.9		2.8		28.9		63.2
Finance leases(c)	3.4		2.9		1.5		0.8		0.8		13.1		22.5
Funding of pension obligations (d) (e)	105.0		—		—		—		—		—		105.0
Funding of PBOP obligations (d) (e)	2.9		—		—		—		—		—		2.9
Estimated future annual long-term contractual costs (f)	998.8		941.6		946.5		897.5		881.9		4,785.2		9,451.5
Total (g)	$	1,971.1	$	2,523.7	$	2,645.9	$	3,037.1	$	2,362.6	$	17,662.6	$	30,203.0

CL&P
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Long-term debt maturities (a)	$	—	$	—	$	—	$	400.0	$	139.8	$	2,975.5	$	3,515.3
Estimated interest payments on existing debt (b)	153.2		153.2		153.2		148.2		143.2		2,016.2		2,767.2
Operating leases (c)	0.5		0.2		—		—		—		0.1		0.8
Finance leases (c)	2.0		1.5		—		—		—		—		3.5
Funding of pension obligations (d) (e)	23.2		—		—		—		—		—		23.2
Estimated future annual long-term contractual costs (f)	558.2		547.9		602.7		614.3		605.8		2,875.9		5,804.8
Total (g)	$	737.1	$	702.8	$	755.9	$	1,162.5	$	888.8	$	7,867.7	$	12,114.8

(a) Long-term debt maturities exclude the CYAPC pre-1983 spent nuclear fuel obligation, net unamortized premiums, discounts and debt issuance costs, and other fair value adjustments.

(b) Estimated interest payments on fixed-rate debt are calculated by multiplying the coupon rate on the debt by its scheduled notional amount outstanding for the period of measurement.  

(c) The operating and finance lease obligations include interest.

(d) Amounts are not included on our balance sheets.  

(e) These amounts represent expected pension and PBOP contributions for 2020.  Future contributions will vary depending on many factors, including the performance of existing plan assets, valuation of the plans' liabilities and long-term discount rates.   

(f) Other than certain derivative contracts held by the regulated companies, these obligations are not included on our balance sheets.  

(g) Does not include other long-term liabilities recorded on our balance sheet, such as environmental reserves, employee medical insurance, workers compensation and long-term disability insurance reserves, ARO liability reserves and other reserves, as we cannot make reasonable estimates of the timing of payments. Also, does not include amounts not included on our balance sheets for future funding of Eversource's equity method investments, as we cannot make reasonable estimates of the periods or the investment contributions.

For further information regarding our contractual obligations and commercial commitments, see Note 7, "Asset Retirement Obligations," Note 8, "Short-Term Debt," Note 9, "Long-Term Debt," Note 10, "Rate Reduction Bonds and Variable Interest Entities," Note 11A, "Employee Benefits - Pension Benefits and Postretirement Benefits Other Than Pension," Note 13, "Commitments and Contingencies," and Note 15, "Leases," to the financial statements.

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RESULTS OF OPERATIONS – EVERSOURCE ENERGY AND SUBSIDIARIES

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for Eversource for the years ended December 31, 2019 and 2018 included in this Annual Report on Form 10-K: 

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		Increase/(Decrease)
Operating Revenues	$	8,526.5	$	8,448.2	$	78.3
Operating Expenses:
Purchased Power, Fuel and Transmission	3,040.2		3,139.0		(98.8		)
Operations and Maintenance	1,363.1		1,335.2		27.9
Depreciation	885.3		819.9		65.4
Amortization	195.4		252.0		(56.6		)
Energy Efficiency Programs	501.4		472.4		29.0
Taxes Other Than Income Taxes	711.0		729.8		(18.8		)
Impairment of Northern Pass Transmission	239.6		—		239.6
Total Operating Expenses	6,936.0		6,748.3		187.7
Operating Income	1,590.5		1,699.9		(109.4		)
Interest Expense	533.2		498.8		34.4
Other Income, Net	132.8		128.4		4.4
Income Before Income Tax Expense	1,190.1		1,329.5		(139.4		)
Income Tax Expense	273.5		289.0		(15.5		)
Net Income	916.6		1,040.5		(123.9		)
Net Income Attributable to Noncontrolling Interests	7.5		7.5		—
Net Income Attributable to Common Shareholders	$	909.1	$	1,033.0	$	(123.9	)

Operating Revenues

Sales Volumes: A summary of our retail electric GWh sales volumes, our firm natural gas MMcf sales volumes, and our water MG sales volumes, and percentage changes, is as follows:  

	Electric				Firm Natural Gas				Water
	Sales Volumes (GWh)		Percentage Decrease		Sales Volumes (MMcf)		Percentage Increase		Sales Volumes (MG)		Percentage Decrease
	2019	2018 (1)			2019	2018 (2)			2019	2018
Traditional	7,685	7,915	(2.9	)%	—	—	—	%	2,161	2,252	(4.0	)%
Decoupled and Special Contracts (3)	43,934	45,466	(3.4	)%	107,806	105,957	1.7	%	21,370	21,479	(0.5	)%
Total Sales Volumes	51,619	53,381	(3.3	)%	107,806	105,957	1.7	%	23,531	23,731	(0.8	)%

⁽¹⁾   Effective February 1, 2018, NSTAR Electric operated entirely under a decoupled rate structure. The 2018 sales volumes for NSTAR Electric have been recast to present January 2018 as decoupled to conform to the current year presentation.

⁽²⁾   Effective November 15, 2018, Yankee Gas operated under a decoupled rate structure. The 2018 sales volumes for Yankee Gas have been recast to present 2018 as decoupled to conform to the current year presentation.

⁽³⁾ Special contracts are unique to Yankee Gas natural gas distribution customers who take service under such an arrangement and generally specify the amount of distribution revenue to be paid to Yankee Gas regardless of the customers' usage.

Weather, fluctuations in energy supply costs, conservation measures (including utility-sponsored energy efficiency programs), and economic conditions affect customer energy usage and water consumption.  Industrial sales volumes are less sensitive to temperature variations than residential and commercial sales volumes.  In our service territories, weather impacts both electric and water sales volumes during the summer and both electric and natural gas sales volumes during the winter; however, natural gas sales volumes are more sensitive to temperature variations than electric sales volumes.  Customer heating or cooling usage may not directly correlate with historical levels or with the level of degree-days that occur.

Fluctuations in retail electric sales volumes at PSNH impact earnings ("Traditional" in the table above).  For CL&P, NSTAR Electric, Yankee Gas, and NSTAR Gas, fluctuations in retail sales volumes do not impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms ("Decoupled" in the table above).  These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized.  Fluctuations in water sales volumes largely do not impact earnings as our Connecticut water distribution business is also decoupled.

Operating Revenues: Operating Revenues by segment increased/(decreased) in 2019, as compared to 2018, as follows:

(Millions of Dollars)	Increase/(Decrease)
Electric Distribution	$	19.3
Natural Gas Distribution	40.0
Electric Transmission	102.7
Water Distribution	2.6
Other	92.2
Eliminations	(178.5		)
Total Operating Revenues	$	78.3

Electric and Natural Gas Distribution Revenues:

Base Distribution Revenues:

• Base electric distribution revenues increased $107.7 million in 2019, as compared to 2018, due primarily to the impact of CL&P's base distribution rate increases effective May 1, 2019 and May 1, 2018, which include recovery of storm costs and certain other items that do not impact earnings, an NSTAR Electric base distribution rate increase effective January 1, 2019, and a PSNH temporary base distribution rate increase effective July 1, 2019.

• Base natural gas distribution revenues increased $7.6 million in 2019, as compared to 2018, due primarily to the impact of the Yankee Gas base distribution rate increase effective November 15, 2018.

Tracked Distribution Revenues: Tracked distribution revenues consist of certain costs that are recovered from customers in retail rates through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs has no impact on earnings.  Costs recovered through cost tracking mechanisms include, among others, energy supply and natural gas supply procurement and other energy-related costs, and electric retail transmission charges, which decreased significantly due primarily to the lower federal corporate income tax rate that was reflected effective January 1, 2019. In addition, cost tracking mechanisms include energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), and additionally for NSTAR Electric, pension and PBOP benefits and net metering for distributed generation. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties. However, tracked revenues do include certain incentives earned, return on rate base, and carrying charges that are billed in rates to customers, which do impact earnings.

Tracked distribution revenues increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

(Millions of Dollars)	Electric Distribution			Natural Gas Distribution
Retail Tariff Tracked Revenues
Energy supply procurement	$	—		$	24.2
Retail transmission (1)	(123.3		)	N/A
Other distribution tracking mechanisms	18.7			13.8
Wholesale Market Sales Revenue	36.2			(2.1		)

⁽¹⁾ The decrease reflects a decrease in the retail transmission rate billed to customers that was adjusted on January 1, 2019 to reflect the lower federal corporate income tax rate.

Electric Transmission Revenues:  Electric transmission revenues increased $102.7 million in 2019, as compared to 2018, due primarily to continued investment in our transmission infrastructure and a higher recovery of tracked costs.

Other Revenues and Eliminations: Other revenues primarily include the revenues of Eversource's service company, most of which are eliminated in consolidation. Eliminations are also primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business.

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Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity and natural gas on behalf of our customers.  These electric and natural gas supply costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs).  Purchased Power, Fuel and Transmission expense increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

(Millions of Dollars)	Increase/(Decrease)
Electric Distribution	$	88.1
Natural Gas Distribution	21.8
Transmission	(124.4		)
Eliminations	(84.3		)
Total Purchased Power, Fuel and Transmission	$	(98.8	)

The increase in purchased power expense at the electric distribution business in 2019 as compared to 2018, was driven primarily by a new zero-carbon power purchase agreement entered into in 2019, as required by regulation in Connecticut, from which the energy purchased from Millstone Nuclear Power Station is sold into the market. Additionally, as a result of the sale of PSNH's thermal generation assets on January 10, 2018, and the sale of PSNH's hydroelectric assets on August 26, 2018, PSNH purchased power in place of its self-generation output. The increase in natural gas supply costs at our natural gas distribution business was due primarily to higher average sales volumes.

The decrease in transmission costs in 2019, as compared to 2018, was primarily the result of a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers, and a decrease in costs billed by ISO-NE that support regional grid investments. The retail transmission rate was adjusted on January 1, 2019 to reflect the lower federal corporate income tax rate, resulting in a decrease in the cost of retail transmission service. This was partially offset by an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network.

Operations and Maintenance expense includes tracked costs and costs that are part of base electric, natural gas and water distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance expense increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

(Millions of Dollars)	Increase/(Decrease)
Base Electric Distribution (Non-Tracked Costs):
Employee-related expenses, including labor and benefits	$	(27.6	)
Storm restoration costs	8.8
Shared corporate costs (including computer software depreciation at Eversource Service)	22.3
Operations-related expenses, including vegetation management, vehicles, and outside services	14.6
Other non-tracked operations and maintenance	(2.9		)
Total Base Electric Distribution (Non-Tracked Costs)	15.2
Base Natural Gas Distribution (Non-Tracked Costs) - Increase due primarily to higher shared corporate costs of $10.8 million	16.6
Water Distribution	0.1
Tracked Costs (Electric Distribution, Electric Transmission and Natural Gas Distribution) - Increase due to higher transmission and vegetation management expenses, partially offset by the absence in 2019 of PSNH generation operations expenses due to the sale of its generation assets in 2018, and a decrease in employee-related benefit costs	29.2
Other and eliminations:
Eversource Parent and Other Companies - other operations and maintenance	59.8
Eliminations	(93.0		)
Total Operations and Maintenance	$	27.9

Depreciation expense increased in 2019, as compared to 2018, due primarily to higher utility plant in service balances and new depreciation rates effective with the CL&P distribution rate case settlement agreement.

Amortization expense includes the deferral of energy supply and energy-related costs included in certain regulatory commission-approved cost tracking mechanisms, and the amortization of certain costs.  This deferral adjusts expense to match the corresponding revenues. Energy supply and energy-related costs are recovered from customers in rates and have no impact on earnings.  Amortization decreased in 2019, as compared to 2018, due primarily to the deferral of energy supply and energy-related costs at CL&P and PSNH, partially offset by an increase in storm cost recovery at CL&P, NSTAR Electric and PSNH, and by increased amortization of PSNH's securitized regulatory asset related to the May 2018 RRB issuance of $15.7 million.

Energy Efficiency Programs expense increased in 2019, as compared to 2018, due primarily to an increase in spending for CL&P's and PSNH's energy efficiency programs. The costs for the majority of the state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates and have no impact on earnings. CL&P, NSTAR Electric and PSNH energy efficiency programs will include additional authorized spending totaling approximately $60 million in 2020, as compared to 2019.

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Taxes Other Than Income Taxes expense decreased in 2019, as compared to 2018, due primarily to a decrease of $25.4 million related to CL&P's remittance of energy efficiency funds to the State of Connecticut. Energy efficiency funds collected from CL&P's customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. The decrease is also due to amounts received by PSNH in the third quarter of 2019 relating to a refund of property taxes as a result of a settlement with the town of Bow, New Hampshire ($8.3 million).

Impairment of Northern Pass Transmission reflects an impairment charge of $239.6 million that was recorded in the second quarter of 2019 as a result of the July 19, 2019 New Hampshire Supreme Court decision. The after-tax impact of this impairment charge was $204.4 million.

Interest Expense increased in 2019, as compared to 2018, due primarily to an increase in interest on long-term debt as a result of new debt issuances ($38.9 million), an increase in interest due to the May 2018 PSNH RRB issuance ($6.7 million) and an increase in interest on notes payable ($4.1 million). Partially offsetting these increases were an increase in AFUDC related to debt funds ($5.9 million) and higher other capitalized interest ($17.0 million).

Other Income, Net increased in 2019, as compared to 2018, due primarily to an increase in equity in earnings of unconsolidated affiliates related to Eversource's equity method investments, net of impairment ($38.4 million) and investment income in 2019 compared to investment losses in 2018 ($4.8 million). In 2018, Eversource recognized a $32.9 million other-than-temporary impairment charge to our equity method investment in the Access Northeast project, which was reflected as a loss within equity in earnings. Partially offsetting these increases were a decrease related to pension, SERP and PBOP non-service income components ($29.5 million), lower gains on sales of property ($4.8 million), and a decrease in the recognition of the equity component of the carrying charges related to storm costs recorded in interest income at PSNH ($2.4 million).

Income Tax Expense decreased in 2019, as compared to 2018, due primarily to amortization of EDIT ($32.4 million), by the impairment of NPT in 2019, compared to the write-off of Access Northeast in 2018 ($37.8 million), partially offset by higher pre-tax earnings ($15.0 million), by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($8.4 million), an increase in valuation allowance against state tax credits ($13.3 million), and due to the offset of one-time items relating to federal tax reform and release of tax reserve in 2018 ($18.0 million) that did not occur in 2019. The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue was $51.5 million, offset by current tax benefits of $14.1 million and amortization of EDIT of $37.4 million, for the year ended December 31, 2019, which results in no impact on earnings.

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RESULTS OF OPERATIONS –

THE CONNECTICUT LIGHT AND POWER COMPANY

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P, NSTAR Electric and PSNH for the years ended December 31, 2019 and 2018 included in this Annual Report on Form 10-K:

	For the Years Ended December 31,
	CL&P							NSTAR Electric							PSNH
(Millions of Dollars)	2019		2018		Increase/(Decrease)			2019		2018		Increase/(Decrease)			2019		2018		Increase/(Decrease)
Operating Revenues	$	3,232.6	$	3,096.2	$	136.4		$	3,044.6	$	3,112.9	$	(68.3	)	$	1,065.9	$	1,047.6	$	18.3
Operating Expenses:
Purchased Power, Fuel and Transmission	1,188.2		1,095.2		93.0			1,064.3		1,257.1		(192.8		)	398.4		370.2		28.2
Operations and Maintenance	549.2		506.4		42.8			468.4		462.1		6.3			211.0		210.5		0.5
Depreciation	301.2		278.6		22.6			296.5		276.4		20.1			93.7		92.1		1.6
Amortization of Regulatory Assets, Net	51.6		129.0		(77.4		)	103.7		46.7		57.0			57.7		81.0		(23.3		)
Energy Efficiency Programs	118.2		94.0		24.2			289.2		292.3		(3.1		)	26.0		20.1		5.9
Taxes Other Than Income Taxes	342.5		357.2		(14.7		)	195.6		194.2		1.4			62.6		77.3		(14.7		)
Total Operating Expenses	2,550.9		2,460.4		90.5			2,417.7		2,528.8		(111.1		)	849.4		851.2		(1.8		)
Operating Income	681.7		635.8		45.9			626.9		584.1		42.8			216.5		196.4		20.1
Interest Expense	151.4		151.7		(0.3		)	114.2		105.2		9.0			60.7		60.6		0.1
Other Income, Net	17.6		22.7		(5.1		)	44.6		53.1		(8.5		)	19.2		27.7		(8.5		)
Income Before Income Tax Expense	547.9		506.8		41.1			557.3		532.0		25.3			175.0		163.5		11.5
Income Tax Expense	137.0		129.1		7.9			125.3		148.9		(23.6		)	41.0		47.6		(6.6		)
Net Income	$	410.9	$	377.7	$	33.2		$	432.0	$	383.1	$	48.9		$	134.0	$	115.9	$	18.1

Operating Revenues

Sales Volumes: A summary of our retail electric GWh sales volumes was as follows:

	For the Years Ended December 31,
	2019	2018	Decrease		Percent
CL&P	20,719	21,467	(748	)	(3.5	)%
NSTAR Electric	23,215	23,999	(784	)	(3.3	)%
PSNH	7,685	7,915	(230	)	(2.9	)%

Fluctuations in retail electric sales volumes at PSNH impact earnings.  For CL&P and NSTAR Electric, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms.

Operating Revenues: Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, increased $136.4 million at CL&P and $18.3 million at PSNH, and decreased $68.3 million at NSTAR Electric in 2019, as compared to 2018.

Base Distribution Revenues:

• CL&P's distribution revenues increased $60.8 million due primarily to the impact of its base distribution rate increases effective May 1, 2019 and May 1, 2018, which include recovery of storm costs and certain other items that do not impact earnings.

• NSTAR Electric's distribution revenues increased $27.3 million due primarily to the impact of its base distribution rate increase effective January 1, 2019.

• PSNH's distribution revenues increased $19.6 million due primarily to the impact of its temporary base distribution rate increase effective July 1, 2019.

Tracked Revenues: Tracked revenues consist of certain costs that are recovered from customers in retail rates through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs has no impact on earnings. Costs recovered through cost tracking mechanisms include, among others, energy supply procurement and other energy-related costs, and retail transmission charges, which decreased significantly due primarily to the lower federal corporate income tax rate that was reflected effective January 1, 2019. In addition, cost tracking mechanisms include energy efficiency program costs, restructuring and stranded cost recovery revenues (including securitized RRB charges), and additionally for NSTAR Electric, pension and PBOP benefits and net metering for distributed generation.  Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties. However, tracked revenues do include certain incentives earned, return on rate base, and carrying charges that are billed in rates to customers, which do impact earnings.

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Tracked revenues increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

(Millions of Dollars)	CL&P			NSTAR Electric			PSNH
Retail Tariff Tracked Revenues:
Energy supply procurement	$	26.0		$	(29.9	)	$	3.9
Retail transmission	(10.7		)	(94.0		)	(18.6		)
Other distribution tracking mechanisms	(13.7		)	20.7			11.7
Wholesale Market Sales Revenue	56.8			(3.0		)	(19.1		)

PSNH's energy supply procurement revenues include the absence in 2019 of the recovery of generation rate base return due to the sale of its thermal and hydroelectric generation assets in 2018. Revenues from CL&P's other distribution tracking mechanisms include higher earnings from its capital tracker mechanism effective July 1, 2018 due to increased electric system improvements.

CL&P's wholesale market sales revenue increase was due primarily to a new zero-carbon power purchase agreement entered into in 2019, as required by regulation, from which the energy purchased from Millstone Nuclear Power Station is sold into the market. The decrease in retail transmission at CL&P, NSTAR Electric and PSNH reflects a decrease in the retail transmission rate billed to customers that was adjusted on January 1, 2019 to reflect the lower federal corporate income tax rate.

Transmission Revenues: Transmission revenues increased $59.9 million at CL&P, $27.5 million at NSTAR Electric and $15.3 million at PSNH in 2019, as compared to 2018, due primarily to continued investment in our transmission infrastructure and a higher recovery of tracked costs.

Eliminations: Eliminations are primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business. The impact of eliminations decreased revenues by $27.8 million at CL&P and $13.0 million at NSTAR Electric and increased revenues by $4.5 million at PSNH in 2019, as compared to 2018.

Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity on behalf of CL&P, NSTAR Electric and PSNH's customers.  These energy supply costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power, Fuel and Transmission expense increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

(Millions of Dollars)	CL&P			NSTAR Electric			PSNH
Purchased Power Costs	$	132.7		$	(86.3	)	$	41.7
Transmission Costs	(12.5		)	(93.9		)	(18.0		)
Eliminations	(27.2		)	(12.6		)	4.5
Total Purchased Power, Fuel and Transmission	$	93.0		$	(192.8	)	$	28.2

Purchased Power Costs: Included in purchased power costs are the costs associated with providing electric generation service supply to all customers who have not migrated to third party suppliers and the cost of energy purchase contracts, as required by regulation.

• The increase at CL&P was due primarily to a new zero-carbon power purchase agreement entered into in 2019, as required by regulation, from which the energy purchased from Millstone Nuclear Power Station is sold into the market.

• The decrease at NSTAR Electric was due primarily to a decrease in the volume of power procured on behalf of our customers.

• The increase at PSNH was due primarily to higher purchased power energy expenses that are recovered as a component of the Energy Service and Stranded Cost Recovery Charge tracking mechanisms. As a result of the sale of its thermal generation assets on January 10, 2018 and its hydroelectric generation assets on August 26, 2018, PSNH has purchased power in place of its self-generation output.

Transmission Costs: Included in transmission costs are charges that recover the cost of transporting electricity over high-voltage lines from generation facilities to substations, including costs allocated by ISO-NE to maintain the wholesale electric market.

• The decrease in transmission costs at CL&P was primarily the result of a decrease in costs billed by ISO-NE that support regional grid investment. This was partially offset by an increase in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers and an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network.

• The decrease in transmission costs at NSTAR Electric and PSNH was primarily the result of a decrease in costs billed by ISO-NE that support regional grid investment and a decrease in the retail transmission cost deferral. This was partially offset by an increase in Local Network Service charges.

• The decrease in transmission costs at CL&P, NSTAR Electric and PSNH also pertains to a reduction to the retail transmission rate that was adjusted on January 1, 2019 to reflect the lower federal corporate income tax rate, resulting in a decrease in the cost of retail transmission service.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance expense increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

(Millions of Dollars)	CL&P			NSTAR Electric			PSNH
Base Electric Distribution (Non-Tracked Costs):
Employee-related expenses, including labor and benefits	$	(9.1	)	$	(16.1	)	$	(2.4	)
HEEC Boston Harbor distribution cable costs	—			(6.5		)	—
Storm restoration costs	(1.9		)	10.7			—
Shared corporate costs (including computer software depreciation at Eversource Service)	9.2			10.7			2.4
Operations-related expenses, including vegetation management, vehicles, and outside services	3.6			2.8			8.2
Other non-tracked operations and maintenance	7.3			(4.2		)	0.5
Total Base Electric Distribution (Non-Tracked Costs)	9.1			(2.6		)	8.7
Tracked Costs:
Absence in 2019 of PSNH generation operations expenses due to the 2018 sales of thermal and hydroelectric generation assets	—			—			(10.9		)
Transmission expenses	23.5			2.5			(1.8		)
Other tracked operations and maintenance	10.2			6.4			4.5
Total Tracked Costs	33.7			8.9			(8.2		)
Total Operations and Maintenance	$	42.8		$	6.3		$	0.5

Depreciation increased in 2019, as compared to 2018, due primarily to the following:

• The increase at CL&P was due to higher net plant in service balances and the implementation of new depreciation rates effective with the 2018 CL&P distribution rate case settlement agreement.

• The increase at NSTAR Electric was due to higher net plant in service balances.

• The increase at PSNH was due to higher distribution depreciation expense, partially offset by the sale of the thermal and hydroelectric generation assets in 2018.

Amortization of Regulatory Assets, Net expense includes the deferral of energy supply and energy-related costs included in certain regulatory-approved cost tracking mechanisms, and the amortization of certain costs. This deferral adjusts expense to match the corresponding revenues. Energy supply and energy-related costs are recovered from customers in rates and have no impact on earnings.  

• The increase at NSTAR Electric in 2019, as compared to 2018, was due primarily to an increase in both storm cost recovery and costs associated with low income customers. The remaining increase in amortization was driven by the deferral of energy supply and energy-related costs, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs.

• The decrease at CL&P and PSNH was due primarily to the deferral of energy supply and energy-related costs, partially offset by an increase in storm cost recovery. The decrease at PSNH is also partially offset by $15.7 million of higher amortization of PSNH's securitized regulatory asset related to the May 2018 RRB issuance.

Energy Efficiency Programs expense includes costs of various state energy policy initiatives and expanded energy efficiency programs that are recovered from customers in rates, most of which have no impact on earnings. Energy Efficiency Programs expense increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

• The increase at CL&P and PSNH was due to higher spending for energy efficiency programs.

• The decrease at NSTAR Electric was due to the timing of spending on certain large energy efficiency projects in 2019.

CL&P, NSTAR Electric and PSNH energy efficiency programs will include additional authorized spending of approximately $5 million, $40 million, and $15 million, respectively, in 2020 as compared to 2019.

Taxes Other Than Income Taxes decreased in 2019, as compared to 2018, due primarily to the following:

• The decrease at CL&P was due to a decrease of $25.4 million related to CL&P's remittance of energy efficiency funds to the State of Connecticut. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. The decrease was partially offset by higher property taxes as a result of higher utility plant balances and higher gross earnings taxes (the costs of which are tracked).

• The decrease at PSNH was due to lower property taxes and a refund of property taxes as a result of a settlement with the town of Bow, New Hampshire ($8.3 million).

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Interest Expense increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

• The decrease at CL&P was due to lower interest on long-term debt ($2.6 million), an increase in AFUDC related to debt funds ($0.8 million), and lower amortization of debt discounts and premiums, net ($0.8 million), partially offset by an increase in interest expense on regulatory deferrals ($2.2 million) and an increase in interest on notes payable ($1.4 million).

• The increase at NSTAR Electric was due to higher interest on long-term debt ($8.1 million).

• Interest expense at PSNH did not significantly change as the increase in interest due to the May 2018 RRB issuance ($6.7 million) was offset by a decrease in interest expense on regulatory deferrals ($3.1 million), a decrease in interest on notes payable ($2.0 million) and an increase in AFUDC related to debt funds ($1.5 million).

Other Income, Net decreased in 2019, as compared to 2018, due primarily to the following:

• The decrease at CL&P was due to a decrease related to pension, SERP and PBOP non-service income components ($9.0 million), partially offset by investment income in 2019 compared to investment losses in 2018 ($5.3 million).

• The decrease at NSTAR Electric was due to a decrease related to pension, SERP and PBOP non-service income components ($12.5 million) and an increase in investment losses in 2019 compared to 2018 ($2.7 million), partially offset by an increase in AFUDC related to equity funds ($4.2 million) and an increase in amounts related to officers' life insurance policies ($2.8 million).

• The decrease at PSNH was due to a decrease related to pension, SERP and PBOP non-service income components ($5.0 million), the absence in 2019 of a gain on the sale of property ($4.4 million) and a decrease in the recognition of the equity component of the carrying charges related to storm costs recorded in interest income ($2.4 million). Partially offsetting these decreases was an increase in AFUDC related to equity funds ($3.4 million).

Income Tax Expense increased/(decreased) in 2019, as compared to 2018, due primarily to the following:

• The increase at CL&P was due to higher pre-tax earnings ($8.6 million) and an increase in a valuation allowance against state tax credits ($9.8 million). These increases were partially offset by amortization of EDIT ($5.8 million), return to provision ($3.0 million), lower state taxes ($1.3 million), and by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.4 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue was $7.9 million, offset by a current tax benefit of $2.1 million and amortization of EDIT of $5.8 million for the year ended December 31, 2019, which results in no impact on earnings.

• The decrease at NSTAR Electric was due to amortization of EDIT ($22.9 million), return to provision ($1.3 million), items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($6.3 million) and partially offset by higher pre-tax earnings ($5.4 million) and higher state taxes ($1.5 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue was $31.5 million, offset by a current tax benefit of $8.6 million and amortization of EDIT of $22.9 million for the year ended December 31, 2019, which results in no impact on earnings.

• The decrease at PSNH was due to lower state taxes ($4.4 million), return to provision ($1.1 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($3.8 million). These decreases were partially offset by higher pre-tax earnings ($2.7 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue was $5.6 million, offset by a current tax benefit of $1.6 million and amortization of EDIT of $4.0 million for the year ended December 31, 2019, which results in no impact on earnings.

EARNINGS SUMMARY

CL&P's earnings increased $33.2 million in 2019, as compared to 2018, due primarily to base distribution rate increases effective May 1, 2019 and May 1, 2018, an increase in transmission earnings driven by a higher transmission rate base, and, effective July 1, 2018, higher earnings from its capital tracker mechanism due to increased electric system improvements. The earnings increase was partially offset by higher operations and maintenance expense, higher depreciation expense, lower non-service income from our benefit plans, and higher property tax expense.

NSTAR Electric's earnings increased $48.9 million in 2019, as compared to 2018, due primarily to the base distribution rate increase effective January 1, 2019, an increase in transmission earnings driven by a higher transmission rate base, and higher earnings from its solar generation capital tracker mechanism. The earnings increase was partially offset by higher depreciation expense and higher interest expense.

PSNH's earnings increased $18.1 million in 2019, as compared to 2018, due primarily to the temporary base distribution rate increase effective July 1, 2019 and an increase in transmission earnings driven by a higher transmission rate base. The earnings increase was partially offset by the absence in 2019 of generation earnings as a result of the sale of its generation assets in 2018, higher operations and maintenance expense, the absence in 2019 of a gain on the sale of property in 2018, and lower non-service income from our benefit plans.

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LIQUIDITY

Cash Flows: CL&P had cash flows provided by operating activities of $726.4 million in 2019, as compared to $588.1 million in 2018.  The increase in operating cash flows was due primarily to the timing of cash payments made on our accounts payable and collections on our accounts receivable, a decrease in 2019 of approximately $98 million of storm restoration cost payments, an increase related to the timing of cash collected for regulatory tracking mechanisms, and a decrease in 2019 of $17.2 million of pension contributions. Partially offsetting these favorable impacts were higher income tax payments made in 2019 of $14.5 million, and the timing of other working capital items.

NSTAR Electric had cash flows provided by operating activities of $698.3 million in 2019, as compared to $780.5 million in 2018.  The decrease in operating cash flows was due primarily to the timing of collections for regulatory tracking mechanisms, which were significantly impacted by the timing of collections of purchased power and transmission costs, and the timing of cash payments made on our accounts payable and other working capital items. Partially offsetting these unfavorable impacts were a decrease in 2019 of approximately $45 million of storm restoration cost payments, the timing of cash collections on our accounts receivable, a decrease in 2019 of $55.4 million of pension and PBOP cash contributions, and lower income tax payments made in 2019 of $42.1 million.

PSNH had cash flows provided by operating activities of $274.4 million in 2019, as compared to $259.9 million in 2018.  The increase in operating cash flows was due primarily to the timing of collections on our accounts receivable and cash payments made on our accounts payable, and lower income tax payments made in 2019 of $23.9 million. Partially offsetting these favorable impacts were $15.4 million of pension contributions made in 2019 and the timing of other working capital items.

For further information on CL&P's, NSTAR Electric's and PSNH's liquidity and capital resources, see "Liquidity" and "Business Development and Capital Expenditures" included in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

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Item 7A.    Quantitative and Qualitative Disclosures about Market Risk

Market Risk Information

Commodity Price Risk Management:  Our regulated companies enter into energy contracts to serve our customers, and the economic impacts of those contracts are passed on to our customers.  Accordingly, the regulated companies have no exposure to loss of future earnings or fair values due to these market risk-sensitive instruments.  Eversource's Energy Supply Risk Committee, comprised of senior officers, reviews and approves all large-scale energy related transactions entered into by its regulated companies.

Other Risk Management Activities

We have an Enterprise Risk Management (ERM) program for identifying the principal risks of the Company.  Our ERM program involves the application of a well-defined, enterprise-wide methodology designed to allow our Risk Committee, comprised of our senior officers of the Company, to identify, categorize, prioritize, and mitigate the principal risks to the Company.  The ERM program is integrated with other assurance functions throughout the Company including Compliance, Auditing, and Insurance to ensure appropriate coverage of risks that could impact the Company.  In addition to known risks, ERM identifies emerging risks to the Company, through participation in industry groups, discussions with management and in consultation with outside advisers.  Our management then analyzes risks to determine materiality, likelihood and impact, and develops mitigation strategies.  Management broadly considers our business model, the utility industry, the global economy, climate change, sustainability and the current environment to identify risks.  The Finance Committee of the Board of Trustees is responsible for oversight of the Company's ERM program and enterprise-wide risks as well as specific risks associated with insurance, credit, financing, investments, pensions and overall system security including cyber security.  The findings of the ERM process are periodically discussed with the Finance Committee of our Board of Trustees, as well as with other Board Committees or the full Board of Trustees, as appropriate, including reporting on how these issues are being measured and managed.  However, there can be no assurances that the ERM process will identify or manage every risk or event that could impact our financial position, results of operations or cash flows.

Interest Rate Risk Management:  We manage our interest rate risk exposure in accordance with our written policies and procedures by maintaining a mix of fixed and variable rate long-term debt.  As of December 31, 2019, all of our long-term debt except for $11.6 million of fees and interest due for CYAPC's spent nuclear fuel disposal costs, was at a fixed interest rate.  

Credit Risk Management:  Credit risk relates to the risk of loss that we would incur as a result of non-performance by counterparties pursuant to the terms of our contractual obligations.  We serve a wide variety of customers and transact with suppliers that include IPPs, industrial companies, natural gas and electric utilities, oil and natural gas producers, financial institutions, and other energy marketers.  Margin accounts exist within this diverse group, and we realize interest receipts and payments related to balances outstanding in these margin accounts.  This wide customer and supplier mix generates a need for a variety of contractual structures, products and terms that, in turn, require us to manage the portfolio of market risk inherent in those transactions in a manner consistent with the parameters established by our risk management process.

Our regulated companies are subject to credit risk from certain long-term or high-volume supply contracts with energy marketing companies.  Our regulated companies manage the credit risk with these counterparties in accordance with established credit risk practices and monitor contracting risks, including credit risk.  As of December 31, 2019, our regulated companies held collateral (letters of credit or cash) of $20.0 million from counterparties related to our standard service contracts. As of December 31, 2019, Eversource had $19.3 million of cash posted with ISO-NE related to energy transactions.

For further information on cash collateral deposited and posted with counterparties, see Note 1O, "Summary of Significant Accounting Policies - Supplemental Cash Flow Information," to the financial statements.

If the respective unsecured debt ratings of Eversource or its subsidiaries were reduced to below investment grade by either Moody's or S&P, certain of Eversource's contracts would require additional collateral in the form of cash to be provided to counterparties and independent system operators.  Eversource would have been and remains able to provide that collateral.  

48

Item 8.    Financial Statements and Supplementary Data

Eversource
	Company Report on Internal Controls Over Financial Reporting
	Reports of Independent Registered Public Accounting Firm
	Consolidated Financial Statements
CL&P
	Company Report on Internal Controls Over Financial Reporting
	Report of Independent Registered Public Accounting Firm
	Financial Statements
NSTAR Electric
	Company Report on Internal Controls Over Financial Reporting
	Report of Independent Registered Public Accounting Firm
	Consolidated Financial Statements
PSNH
	Company Report on Internal Controls Over Financial Reporting
	Report of Independent Registered Public Accounting Firm
	Consolidated Financial Statements

49

Company Report on Internal Controls Over Financial Reporting

Eversource Energy

Management is responsible for the preparation, integrity, and fair presentation of the accompanying consolidated financial statements of Eversource Energy and subsidiaries (Eversource or the Company) and of other sections of this annual report.  Eversource's internal controls over financial reporting were audited by Deloitte & Touche LLP.

Management is responsible for establishing and maintaining adequate internal controls over financial reporting.  The Company's internal control framework and processes have been designed to provide reasonable 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.  There are inherent limitations of internal controls over financial reporting that could allow material misstatements due to error or fraud to occur and not be prevented or detected on a timely basis by employees during the normal course of business.  Additionally, internal controls over financial reporting may become inadequate in the future due to changes in the business environment.  

Under the supervision and with the participation of the principal executive officer and principal financial officer, Eversource conducted an evaluation of the effectiveness of internal controls over financial reporting based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).  Based on this evaluation under the framework in COSO, management concluded that internal controls over financial reporting were effective as of December 31, 2019.

February 26, 2020

50

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholders and the Board of Trustees of Eversource Energy

Opinion on Internal Control over Financial Reporting

We have audited the internal control over financial reporting of Eversource Energy and subsidiaries (the “Company”) as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 2019, of the Company and our report dated February 26, 2020, expressed an unqualified opinion on those financial statements.

Basis for Opinion

The Company’s management is responsible 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 Company Report on Internal Controls Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) 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 (3) 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/ Deloitte & Touche LLP

Hartford, Connecticut

February 26, 2020

51

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Trustees and Shareholders of Eversource Energy:

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of Eversource Energy and subsidiaries (the “Company”) as of December 31, 2019 and 2018, the related consolidated statements of income, comprehensive income, common shareholders’ equity, and cash flows, for each of the three years in the period ended December 31, 2019, and the related notes and the schedules listed in the Index at Item 15 of Part IV (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 26, 2020, expressed an unqualified opinion on the Company’s internal control over financial reporting.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matter

The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

Regulatory Accounting - Impact of Rate Regulation on the Financial Statements - Refer to Note 2 to the Financial Statements

Critical Audit Matter Description

The Company’s utility companies are subject to rate regulation by one or more of the Federal Energy Regulatory Commission and the Connecticut, Massachusetts, and New Hampshire state public utility authorities (the “Commissions”) that is based on cost recovery and meets the criteria for application of accounting guidance for rate-regulated operations, which considers the effect of regulation on the timing of the recognition of certain revenues and expenses. The regulated companies’ financial statements reflect the effects of the rate-making process. The rates charged to the customers of the Company’s regulated companies are designed to collect each company’s cost to provide service, plus a return on investment.

The application of accounting guidance for rate-regulated enterprises results in recording regulatory assets and liabilities.  Regulatory assets represent the deferral of incurred costs that are probable of future recovery in customer rates.  Regulatory assets are amortized as the incurred costs are recovered through customer rates.  In some cases, the Company records regulatory assets before approval for recovery has been received from the applicable regulatory commission.  The Company must use judgment to conclude that costs deferred as regulatory assets are probable of future recovery.  The Company bases its conclusion on certain factors, including, but not limited to, regulatory precedent.  Regulatory liabilities represent either revenues received from customers to fund expected costs that have not yet been incurred or probable future refunds to customers.

The Company uses judgment when recording regulatory assets and liabilities; however, regulatory commissions can reach different conclusions about the recovery of costs, and those conclusions could have a material impact on the financial statements.  Management believes it is probable that each of the regulated companies will recover its respective investment in long-lived assets, including regulatory assets. If management were to determine that it could no longer apply the accounting guidance applicable to rate-regulated enterprises to any of the regulated companies' operations, or if management could not conclude it is probable that costs would be recovered from customers in future rates, the costs would be charged to net income in the period in which the determination is made.

52

Accounting for the economics of rate-regulation impacts multiple financial statement line items and disclosures, such as regulated property, plant, and equipment, regulatory assets and liabilities, operating revenues and depreciation expense. While management has indicated it expects to recover costs from customers through regulated rates, there is a risk that the Commissions will not approve full recovery of such costs or full recovery of all amounts invested in the utility business and a reasonable return on that investment. We identified the impact of rate-regulation as a critical audit matter due to the significant judgments made by management to support its assertions about impact of future regulatory orders on the financial statements. Management judgments include assessing the probability of recovery in future rates of incurred costs and a refund to customers. Given that management’s accounting judgments are based on assumptions about the outcome of future decisions by the Commissions, auditing these judgments requires specialized knowledge of accounting for rate regulation and the rate setting process due to its inherent complexities.

How the Critical Audit Matter Was Addressed in the Audit

Our audit procedures related to the uncertainty of future decisions by the Commissions included the following, among others:

We tested the effectiveness of management’s controls over the evaluation of the likelihood of (1) the recovery in future rates of costs incurred as property, plant, and equipment and deferred as regulatory assets, and (2) a refund or a future reduction in rates that should be reported as regulatory liabilities. We tested the effectiveness of management’s controls over the initial recognition of amounts as property, plant, and equipment; regulatory assets or liabilities; and the monitoring and evaluation of regulatory developments that may affect the likelihood of recovering costs in future rates, a refund, or a future reduction in rates.

We evaluated the Company’s disclosures related to the applicability and impacts of rate regulation, including the balances recorded and regulatory developments disclosed in the financial statements.

We read relevant regulatory orders issued by the Commissions for the Company and other public utilities in Connecticut, Massachusetts, and New Hampshire, regulatory statutes, interpretations, procedural memorandums, filings made by intervenors, and other publicly available information to assess the likelihood of recovery in future rates or of a future refund or reduction in rates based on precedence of the Commissions’ treatment of similar costs under similar circumstances. We evaluated the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.

For regulatory matters in process, we inspected the Company’s filings with the Commissions and the filings with the Commissions by intervenors that may impact the Company’s future rates, for any evidence that might contradict management’s assertions.

We obtained the regulatory orders and analysis from management that support the probability of recovery, refund, or future reductions in rates for regulatory assets and liabilities to assess management’s assertion that amounts are probable of recovery, refund, or a future reduction in rates.

/s/ Deloitte & Touche LLP

Hartford, Connecticut

February 26, 2020

We have served as the Company’s auditor since 2002.

53

EVERSOURCE ENERGY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

	As of December 31,
(Thousands of Dollars)	2019			2018
ASSETS
Current Assets:
Cash	$	15,432		$	108,068
Receivables, Net	989,383			994,055
Unbilled Revenues	181,006			176,285
Fuel, Materials, Supplies and REC Inventory	235,471			238,042
Regulatory Assets	651,112			514,779
Prepayments and Other Current Assets	342,135			260,995
Total Current Assets	2,414,539			2,292,224
Property, Plant and Equipment, Net	27,585,470			25,610,428
Deferred Debits and Other Assets:
Regulatory Assets	4,863,639			4,631,137
Goodwill	4,427,266			4,427,266
Investments in Unconsolidated Affiliates	871,633			464,286
Marketable Securities	449,130			417,508
Other Long-Term Assets	512,238			398,407
Total Deferred Debits and Other Assets	11,123,906			10,338,604
Total Assets	$	41,123,915		$	38,241,256
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	889,084		$	910,000
Long-Term Debt – Current Portion	327,411			837,319
Rate Reduction Bonds – Current Portion	43,210			52,332
Accounts Payable	1,147,872			1,119,995
Regulatory Liabilities	361,152			370,230
Other Current Liabilities	836,834			823,006
Total Current Liabilities	3,605,563			4,112,882
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	3,755,777			3,506,030
Regulatory Liabilities	3,658,042			3,609,475
Derivative Liabilities	338,710			379,562
Asset Retirement Obligations	488,511			466,236
Accrued Pension, SERP and PBOP	1,370,245			962,510
Other Long-Term Liabilities	810,553			730,100
Total Deferred Credits and Other Liabilities	10,421,838			9,653,913
Long-Term Debt	13,770,828			12,248,743
Rate Reduction Bonds	540,122			583,331
Noncontrolling Interest - Preferred Stock of Subsidiaries	155,570			155,570
Common Shareholders' Equity:
Common Shares	1,729,292			1,669,392
Capital Surplus, Paid In	7,087,768			6,241,222
Retained Earnings	4,177,048			3,953,974
Accumulated Other Comprehensive Loss	(65,059		)	(60,000		)
Treasury Stock	(299,055		)	(317,771		)
Common Shareholders' Equity	12,629,994			11,486,817
Commitments and Contingencies (Note 13)
Total Liabilities and Capitalization	$	41,123,915		$	38,241,256

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

54

EVERSOURCE ENERGY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

	For the Years Ended December 31,
(Thousands of Dollars, Except Share Information)	2019		2018		2017
Operating Revenues	$	8,526,470	$	8,448,201	$	7,751,952
Operating Expenses:
Purchased Power, Fuel and Transmission	3,040,160		3,138,969		2,535,271
Operations and Maintenance	1,363,113		1,335,213		1,307,052
Depreciation	885,278		819,930		773,802
Amortization	195,380		252,026		89,986
Energy Efficiency Programs	501,369		472,380		480,835
Taxes Other Than Income Taxes	711,035		729,753		676,757
Impairment of Northern Pass Transmission	239,644		—		—
Total Operating Expenses	6,935,979		6,748,271		5,863,703
Operating Income	1,590,491		1,699,930		1,888,249
Interest Expense	533,197		498,805		421,755
Other Income, Net	132,777		128,366		107,913
Income Before Income Tax Expense	1,190,071		1,329,491		1,574,407
Income Tax Expense	273,499		288,972		578,892
Net Income	916,572		1,040,519		995,515
Net Income Attributable to Noncontrolling Interests	7,519		7,519		7,519
Net Income Attributable to Common Shareholders	$	909,053	$	1,033,000	$	987,996
Basic Earnings Per Common Share	$	2.83	$	3.25	$	3.11
Diluted Earnings Per Common Share	$	2.81	$	3.25	$	3.11
Weighted Average Common Shares Outstanding:
Basic	321,416,086		317,370,369		317,411,097
Diluted	322,941,636		317,993,934		318,031,580

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

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	For the Years Ended December 31,
(Thousands of Dollars)	2019			2018			2017
Net Income	$	916,572		$	1,040,519		$	995,515
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	1,393			1,756			1,974
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,166			(547		)	(350		)
Changes in Funded Status of Pension, SERP and PBOP Benefit Plans	(7,618		)	5,194			(2,745		)
Other Comprehensive (Loss)/Income, Net of Tax	(5,059		)	6,403			(1,121		)
Comprehensive Income Attributable to Noncontrolling Interests	(7,519		)	(7,519		)	(7,519		)
Comprehensive Income Attributable to Common Shareholders	$	903,994		$	1,039,403		$	986,875

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

55

EVERSOURCE ENERGY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

	Common Shares			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information)	Shares	Amount
Balance as of January 1, 2017	316,885,808	$	1,669,392	$	6,250,224		$	3,175,171		$	(65,282	)	$	(317,771	)	$	10,711,734
Net Income							995,515									995,515
Dividends on Common Shares - $1.90 Per Share							(602,083		)							(602,083		)
Dividends on Preferred Stock							(7,519		)							(7,519		)
Long-Term Incentive Plan Activity				(10,834		)										(10,834		)
Other Changes in Shareholders' Equity				550												550
Other Comprehensive Loss										(1,121		)				(1,121		)
Balance as of December 31, 2017	316,885,808	1,669,392		6,239,940			3,561,084			(66,403		)	(317,771		)	11,086,242
Net Income							1,040,519									1,040,519
Dividends on Common Shares - $2.02 Per Share							(640,110		)							(640,110		)
Dividends on Preferred Stock							(7,519		)							(7,519		)
Long-Term Incentive Plan Activity				(543		)										(543		)
Other Changes in Shareholders' Equity				1,825												1,825
Other Comprehensive Income										6,403						6,403
Balance as of December 31, 2018	316,885,808	1,669,392		6,241,222			3,953,974			(60,000		)	(317,771		)	11,486,817
Net Income							916,572									916,572
Dividends on Common Shares - $2.14 Per Share							(685,979		)							(685,979		)
Dividends on Preferred Stock							(7,519		)							(7,519		)
Issuance of Common Shares - $5 par value	11,980,000	59,900		808,650												868,550
Long-Term Incentive Plan Activity				3,434												3,434
Issuance of Treasury Shares	1,014,837			50,758									18,716			69,474
Capital Stock Expense				(16,296		)										(16,296		)
Other Comprehensive Loss										(5,059		)				(5,059		)
Balance as of December 31, 2019	329,880,645	$	1,729,292	$	7,087,768		$	4,177,048		$	(65,059	)	$	(299,055	)	$	12,629,994

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

56

EVERSOURCE ENERGY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
(Thousands of Dollars)	2019			2018			2017
Operating Activities:
Net Income	$	916,572		$	1,040,519		$	995,515
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	885,278			819,930			773,802
Deferred Income Taxes	209,812			174,812			491,630
Uncollectible Expense	63,446			61,337			44,453
Pension, SERP and PBOP Expense, Net	22,000			5,498			22,454
Pension and PBOP Contributions	(121,782		)	(194,947		)	(242,800		)
Regulatory (Under)/Over Recoveries, Net	(124,870		)	34,920			(47,935		)
Amortization	195,380			252,026			89,986
Payments Related to CYAPC's DOE Pre-1983 Spent Nuclear Fuel Obligation	(29,000		)	(145,000		)	—
Proceeds from DOE Spent Nuclear Fuel Litigation	68,840			—			—
Impairment of Northern Pass Transmission	239,644			—			—
Other	(196,087		)	(111,225		)	(204,421		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(98,716		)	(141,433		)	(117,155		)
Fuel, Materials, Supplies and REC Inventory	(8,074		)	(831		)	(9,223		)
Taxes Receivable/Accrued, Net	(16,129		)	(67,770		)	52,284
Accounts Payable	14,866			24,481			56,067
Other Current Assets and Liabilities, Net	(11,603		)	78,226			91,545
Net Cash Flows Provided by Operating Activities	2,009,577			1,830,543			1,996,202
Investing Activities:
Investments in Property, Plant and Equipment	(2,911,489		)	(2,569,936		)	(2,348,105		)
Proceeds from Sales of Marketable Securities	566,592			900,749			832,903
Proceeds from Sales of Marketable Securities Used to Pay Pre-1983 Spent Nuclear Fuel Obligation	—			145,000			—
Purchases of Marketable Securities	(537,258		)	(908,387		)	(810,507		)
Acquisition of Aquarion	—			—			(877,652		)
Investments in Unconsolidated Affiliates, Net	(416,337		)	(205,150		)	(32,634		)
Proceeds from the Sale of PSNH Generation Assets	—			193,924			—
Other Investing Activities	24,204			6,754			5,479
Net Cash Flows Used in Investing Activities	(3,274,288		)	(2,437,046		)	(3,230,516		)
Financing Activities:
Issuance of Common Shares, Net of Issuance Costs	852,254			—			—
Cash Dividends on Common Shares	(663,239		)	(640,110		)	(602,083		)
Cash Dividends on Preferred Stock	(7,519		)	(7,519		)	(7,519		)
Increase/(Decrease) in Notes Payable	325,370			(379,310		)	72,810
(Repayments)/Issuance of Rate Reduction Bonds	(52,332		)	635,663			—
Issuance of Long-Term Debt	1,520,000			2,200,000			2,500,000
Retirement of Long-Term Debt	(801,078		)	(1,050,330		)	(745,000		)
Other Financing Activities	(1,006		)	(28,457		)	(4,754		)
Net Cash Flows Provided by Financing Activities	1,172,450			729,937			1,213,454
Net (Decrease)/Increase in Cash and Restricted Cash	(92,261		)	123,434			(20,860		)
Cash and Restricted Cash - Beginning of Year	209,324			85,890			106,750
Cash and Restricted Cash - End of Year	$	117,063		$	209,324		$	85,890

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

57

Company Report on Internal Controls Over Financial Reporting

The Connecticut Light and Power Company

Management is responsible for the preparation, integrity, and fair presentation of the accompanying financial statements of The Connecticut Light and Power Company (CL&P or the Company) and of other sections of this annual report.  

Management is responsible for establishing and maintaining adequate internal controls over financial reporting.  The Company's internal control framework and processes have been designed to provide reasonable 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.  There are inherent limitations of internal controls over financial reporting that could allow material misstatements due to error or fraud to occur and not be prevented or detected on a timely basis by employees during the normal course of business.  Additionally, internal controls over financial reporting may become inadequate in the future due to changes in the business environment.  

Under the supervision and with the participation of the principal executive officer and principal financial officer, CL&P conducted an evaluation of the effectiveness of internal controls over financial reporting based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).  Based on this evaluation under the framework in COSO, management concluded that internal controls over financial reporting were effective as of December 31, 2019.

February 26, 2020

58

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholder of The Connecticut Light and Power Company:

Opinion on the Financial Statements

We have audited the accompanying balance sheets of The Connecticut Light and Power Company (the “Company”) as of December 31, 2019 and 2018, the related statements of income, comprehensive income, common stockholder’s equity, and cash flows, for each of the three years in the period ended December 31, 2019, and the related notes and the schedule listed in the Index at Item 15 of Part IV (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ Deloitte & Touche LLP

Hartford, Connecticut

February 26, 2020

We have served as the Company’s auditor since 2002.

59

THE CONNECTICUT LIGHT AND POWER COMPANY

BALANCE SHEETS

	As of December 31,
(Thousands of Dollars)	2019		2018
ASSETS
Current Assets:
Cash	$	—	$	87,721
Receivables, Net	400,927		397,026
Accounts Receivable from Affiliated Companies	24,577		23,082
Unbilled Revenues	56,465		56,971
Materials and Supplies	50,700		44,529
Regulatory Assets	178,607		125,155
Prepayments and Other Current Assets	73,184		60,279
Total Current Assets	784,460		794,763
Property, Plant and Equipment, Net	9,625,765		8,909,701
Deferred Debits and Other Assets:
Regulatory Assets	1,557,261		1,505,488
Other Long-Term Assets	217,705		199,767
Total Deferred Debits and Other Assets	1,774,966		1,705,255
Total Assets	$	12,185,191	$	11,409,719
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	63,800	$	—
Long-Term Debt – Current Portion	—		250,000
Accounts Payable	374,698		324,983
Accounts Payable to Affiliated Companies	97,793		26,452
Obligations to Third Party Suppliers	56,952		56,248
Regulatory Liabilities	82,763		109,614
Derivative Liabilities	67,804		55,058
Other Current Liabilities	132,339		161,088
Total Current Liabilities	876,149		983,443
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,244,551		1,166,784
Regulatory Liabilities	1,164,991		1,122,157
Derivative Liabilities	338,594		379,536
Accrued Pension, SERP and PBOP	391,159		282,771
Other Long-Term Liabilities	147,586		155,495
Total Deferred Credits and Other Liabilities	3,286,881		3,106,743
Long-Term Debt	3,518,136		3,004,016
Preferred Stock Not Subject to Mandatory Redemption	116,200		116,200
Common Stockholder's Equity:
Common Stock	60,352		60,352
Capital Surplus, Paid In	2,535,765		2,410,765
Retained Earnings	1,791,392		1,727,899
Accumulated Other Comprehensive Income	316		301
Common Stockholder's Equity	4,387,825		4,199,317
Commitments and Contingencies (Note 13)
Total Liabilities and Capitalization	$	12,185,191	$	11,409,719

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

60

THE CONNECTICUT LIGHT AND POWER COMPANY

STATEMENTS OF INCOME

	For the Years Ended December 31,
(Thousands of Dollars)	2019		2018		2017
Operating Revenues	$	3,232,551	$	3,096,174	$	2,887,359
Operating Expenses:
Purchased Power and Transmission	1,188,202		1,095,187		930,780
Operations and Maintenance	549,167		506,448		502,107
Depreciation	301,188		278,557		249,352
Amortization of Regulatory Assets, Net	51,621		129,021		83,166
Energy Efficiency Programs	118,235		93,977		114,713
Taxes Other Than Income Taxes	342,489		357,147		323,887
Total Operating Expenses	2,550,902		2,460,337		2,204,005
Operating Income	681,649		635,837		683,354
Interest Expense	151,357		151,727		142,973
Other Income, Net	17,531		22,663		22,991
Income Before Income Tax Expense	547,823		506,773		563,372
Income Tax Expense	136,971		129,056		186,646
Net Income	$	410,852	$	377,717	$	376,726

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

STATEMENTS OF COMPREHENSIVE INCOME

	For the Years Ended December 31,
(Thousands of Dollars)	2019			2018			2017
Net Income	$	410,852		$	377,717		$	376,726
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	(26		)	51			334
Changes in Unrealized Gains/(Losses) on Marketable Securities	41			(19		)	(12		)
Other Comprehensive Income, Net of Tax	15			32			322
Comprehensive Income	$	410,867		$	377,749		$	377,048

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

61

THE CONNECTICUT LIGHT AND POWER COMPANY

STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

	Common Stock			Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive (Loss)/Income			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount
Balance as of January 1, 2017	6,035,205	$	60,352	$	2,110,714	$	1,299,374		$	(53	)	$	3,470,387
Net Income						376,726						376,726
Dividends on Preferred Stock						(5,559		)				(5,559		)
Dividends on Common Stock						(254,800		)				(254,800		)
Capital Stock Expenses, Net				51								51
Other Comprehensive Income									322			322
Balance as of December 31, 2017	6,035,205	60,352		2,110,765		1,415,741			269			3,587,127
Net Income						377,717						377,717
Dividends on Preferred Stock						(5,559		)				(5,559		)
Dividends on Common Stock						(60,000		)				(60,000		)
Capital Contributions from Eversource Parent				300,000								300,000
Other Comprehensive Income									32			32
Balance as of December 31, 2018	6,035,205	60,352		2,410,765		1,727,899			301			4,199,317
Net Income						410,852						410,852
Dividends on Preferred Stock						(5,559		)				(5,559		)
Dividends on Common Stock						(341,800		)				(341,800		)
Capital Contributions from Eversource Parent				125,000								125,000
Other Comprehensive Income									15			15
Balance as of December 31, 2019	6,035,205	$	60,352	$	2,535,765	$	1,791,392		$	316		$	4,387,825

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

62

THE CONNECTICUT LIGHT AND POWER COMPANY

STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
(Thousands of Dollars)	2019			2018			2017
Operating Activities:
Net Income	$	410,852		$	377,717		$	376,726
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	301,188			278,557			249,352
Deferred Income Taxes	54,005			54,859			119,295
Uncollectible Expense	15,948			15,831			5,312
Pension, SERP and PBOP Expense	12,761			8,943			9,909
Pension Contributions	(24,000		)	(41,150		)	(2,500		)
Regulatory Underrecoveries, Net	(24,653		)	(53,372		)	(8,017		)
Amortization of Regulatory Assets, Net	51,621			129,021			83,166
Other	(80,266		)	(69,786		)	(42,973		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(52,746		)	(67,334		)	(47,768		)
Materials and Supplies	(6,171		)	3,909			3,612
Taxes Receivable/Accrued, Net	(23,089		)	8,954			(9,688		)
Accounts Payable	102,344			(76,924		)	48,032
Other Current Assets and Liabilities, Net	(11,350		)	18,846			21,860
Net Cash Flows Provided by Operating Activities	726,444			588,071			806,318
Investing Activities:
Investments in Property, Plant and Equipment	(917,532		)	(864,136		)	(824,383		)
Other Investing Activities	714			209			236
Net Cash Flows Used in Investing Activities	(916,818		)	(863,927		)	(824,147		)
Financing Activities:
Cash Dividends on Common Stock	(341,800		)	(60,000		)	(254,800		)
Cash Dividends on Preferred Stock	(5,559		)	(5,559		)	(5,559		)
Increase/(Decrease) in Notes Payable to Eversource Parent	63,800			(69,500		)	(10,600		)
Issuance of Long-Term Debt	500,000			500,000			525,000
Retirement of Long-Term Debt	(250,000		)	(300,000		)	(250,000		)
Capital Contributions from Eversource Parent	125,000			300,000			—
Other Financing Activities	12,291			(7,091		)	15,004
Net Cash Flows Provided by Financing Activities	103,732			357,850			19,045
Net (Decrease)/Increase in Cash and Restricted Cash	(86,642		)	81,994			1,216
Cash and Restricted Cash - Beginning of Year	91,613			9,619			8,403
Cash and Restricted Cash - End of Year	$	4,971		$	91,613		$	9,619

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

63

Company Report on Internal Controls Over Financial Reporting

NSTAR Electric Company

Management is responsible for the preparation, integrity, and fair presentation of the accompanying consolidated financial statements of NSTAR Electric Company and subsidiary (NSTAR Electric or the Company) and of other sections of this annual report.  

Management is responsible for establishing and maintaining adequate internal controls over financial reporting.  The Company's internal control framework and processes have been designed to provide reasonable 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.  There are inherent limitations of internal controls over financial reporting that could allow material misstatements due to error or fraud to occur and not be prevented or detected on a timely basis by employees during the normal course of business.  Additionally, internal controls over financial reporting may become inadequate in the future due to changes in the business environment.  

Under the supervision and with the participation of the principal executive officer and principal financial officer, NSTAR Electric conducted an evaluation of the effectiveness of internal controls over financial reporting based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).  Based on this evaluation under the framework in COSO, management concluded that internal controls over financial reporting were effective as of December 31, 2019.

February 26, 2020

64

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholder of NSTAR Electric Company:

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of NSTAR Electric Company and subsidiary (the “Company”) as of December 31, 2019 and 2018, the related consolidated statements of income, comprehensive income, common stockholder’s equity, and cash flows, for each of the three years in the period ended December 31, 2019, and the related notes and the schedule listed in the Index at Item 15 of Part IV (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ Deloitte & Touche LLP

Hartford, Connecticut

February 26, 2020

We have served as the Company’s auditor since 2012.

65

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED BALANCE SHEETS

	As of December 31,
(Thousands of Dollars)	2019		2018
ASSETS
Current Assets:
Cash	$	52	$	1,606
Receivables, Net	346,785		361,296
Accounts Receivable from Affiliated Companies	29,914		31,344
Unbilled Revenues	37,482		34,518
Materials, Supplies and REC Inventory	124,060		114,202
Regulatory Assets	285,591		241,747
Prepayments and Other Current Assets	31,150		51,960
Total Current Assets	855,034		836,673
Property, Plant and Equipment, Net	9,472,770		8,794,700
Deferred Debits and Other Assets:
Regulatory Assets	1,250,029		1,196,512
Prepaid PBOP	166,058		132,810
Other Long-Term Assets	144,368		109,764
Total Deferred Debits and Other Assets	1,560,455		1,439,086
Total Assets	$	11,888,259	$	11,070,459
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	10,500	$	278,500
Notes Payable to Eversource Parent	30,300		—
Long-Term Debt – Current Portion	95,000		—
Accounts Payable	363,691		384,398
Accounts Payable to Affiliated Companies	96,307		89,636
Obligations to Third Party Suppliers	108,827		109,547
Renewable Portfolio Standards Compliance Obligations	150,429		139,898
Regulatory Liabilities	209,180		190,620
Other Current Liabilities	71,333		74,872
Total Current Liabilities	1,135,567		1,267,471
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,357,265		1,294,467
Regulatory Liabilities	1,516,585		1,513,279
Accrued Pension and SERP	108,243		14,145
Other Long-Term Liabilities	320,629		263,096
Total Deferred Credits and Other Liabilities	3,302,722		3,084,987
Long-Term Debt	3,247,086		2,944,846
Preferred Stock Not Subject to Mandatory Redemption	43,000		43,000
Common Stockholder's Equity:
Common Stock	—		—
Capital Surplus, Paid In	1,813,442		1,633,442
Retained Earnings	2,346,287		2,098,091
Accumulated Other Comprehensive Income/(Loss)	155		(1,378		)
Common Stockholder's Equity	4,159,884		3,730,155
Commitments and Contingencies (Note 13)
Total Liabilities and Capitalization	$	11,888,259	$	11,070,459

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

66

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF INCOME

	For the Years Ended December 31,
(Thousands of Dollars)	2019		2018		2017
Operating Revenues	$	3,044,642	$	3,112,926	$	2,980,629
Operating Expenses:
Purchased Power and Transmission	1,064,289		1,257,073		1,025,414
Operations and Maintenance	468,436		462,100		482,924
Depreciation	296,500		276,372		274,008
Amortization of Regulatory Assets, Net	103,735		46,654		33,831
Energy Efficiency Programs	289,206		292,288		294,053
Taxes Other Than Income Taxes	195,586		194,316		181,959
Total Operating Expenses	2,417,752		2,528,803		2,292,189
Operating Income	626,890		584,123		688,440
Interest Expense	114,198		105,193		105,729
Other Income, Net	44,577		53,066		34,100
Income Before Income Tax Expense	557,269		531,996		616,811
Income Tax Expense	125,313		148,906		242,085
Net Income	$	431,956	$	383,090	$	374,726

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

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	For the Years Ended December 31,
(Thousands of Dollars)	2019		2018			2017
Net Income	$	431,956	$	383,090		$	374,726
Other Comprehensive Income, Net of Tax:
Changes in Funded Status of SERP Benefit Plan	1,084		13			(264		)
Qualified Cash Flow Hedging Instruments	437		437			438
Changes in Unrealized Gains/(Losses) on Marketable Securities	12		(5		)	(3		)
Other Comprehensive Income, Net of Tax	1,533		445			171
Comprehensive Income	$	433,489	$	383,535		$	374,897

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

67

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

	Common Stock			Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive (Loss)/Income			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount
Balance as of January 1, 2017	200	$	—	$	1,500,642	$	1,844,195		$	(1,994	)	$	3,342,843
Net Income						374,726						374,726
Dividends on Preferred Stock						(1,960		)				(1,960		)
Dividends on Common Stock						(272,000		)				(272,000		)
Capital Contributions from Eversource Parent				2,300								2,300
Other Comprehensive Income									171			171
Balance as of December 31, 2017	200	—		1,502,942		1,944,961			(1,823		)	3,446,080
Net Income						383,090						383,090
Dividends on Preferred Stock						(1,960		)				(1,960		)
Dividends on Common Stock						(228,000		)				(228,000		)
Capital Contributions from Eversource Parent				130,500								130,500
Other Comprehensive Income									445			445
Balance as of December 31, 2018	200	—		1,633,442		2,098,091			(1,378		)	3,730,155
Net Income						431,956						431,956
Dividends on Preferred Stock						(1,960		)				(1,960		)
Dividends on Common Stock						(181,800		)				(181,800		)
Capital Contributions from Eversource Parent				180,000								180,000
Other Comprehensive Income									1,533			1,533
Balance as of December 31, 2019	200	$	—	$	1,813,442	$	2,346,287		$	155		$	4,159,884

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

68

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
(Thousands of Dollars)	2019			2018			2017
Operating Activities:
Net Income	$	431,956		$	383,090		$	374,726
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	296,500			276,372			274,008
Deferred Income Taxes	27,107			41,438			110,499
Pension, SERP and PBOP Income, Net	(12,399		)	(21,521		)	(9,509		)
Pension and PBOP Contributions	(6,359		)	(61,751		)	(90,721		)
Regulatory (Under)/Over Recoveries, Net	(60,863		)	149,647			(20,009		)
Amortization of Regulatory Assets, Net	103,735			46,654			33,831
Uncollectible Expense	25,079			22,279			21,252
Other	(78,220		)	(65,523		)	(24,872		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(11,087		)	(26,403		)	(50,896		)
Materials, Supplies and REC Inventory	(9,858		)	(18,685		)	(24,610		)
Taxes Receivable/Accrued, Net	14,147			(33,900		)	39,205
Accounts Payable	(22,659		)	37,140			(20,421		)
Other Current Assets and Liabilities, Net	1,194			51,674			26,849
Net Cash Flows Provided by Operating Activities	698,273			780,511			639,332
Investing Activities:
Investments in Property, Plant and Equipment	(861,391		)	(725,766		)	(719,623		)
Other Investing Activities	86			58			(3,552		)
Net Cash Flows Used in Investing Activities	(861,305		)	(725,708		)	(723,175		)
Financing Activities:
Cash Dividends on Common Stock	(181,800		)	(228,000		)	(272,000		)
Cash Dividends on Preferred Stock	(1,960		)	(1,960		)	(1,960		)
(Decrease)/Increase in Short-Term Debt	(268,000		)	44,500			56,500
Increase in Notes Payable to Eversource Parent	30,300			—			—
Capital Contributions from Eversource Parent	180,000			130,500			2,300
Issuance of Long-Term Debt	400,000			—			700,000
Retirement of Long-Term Debt	—			—			(400,000		)
Other Financing Activities	(3,855		)	108			(1,796		)
Net Cash Flows Provided by/(Used in) Financing Activities	154,685			(54,852		)	83,044
Net Decrease in Cash and Restricted Cash	(8,347		)	(49		)	(799		)
Cash and Restricted Cash - Beginning of Year	14,659			14,708			15,507
Cash and Restricted Cash - End of Year	$	6,312		$	14,659		$	14,708

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

69

Company Report on Internal Controls Over Financial Reporting

Public Service Company of New Hampshire

Management is responsible for the preparation, integrity, and fair presentation of the accompanying consolidated financial statements of Public Service Company of New Hampshire and subsidiaries (PSNH or the Company) and of other sections of this annual report.  

Management is responsible for establishing and maintaining adequate internal controls over financial reporting.  The Company's internal control framework and processes have been designed to provide reasonable 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.  There are inherent limitations of internal controls over financial reporting that could allow material misstatements due to error or fraud to occur and not be prevented or detected on a timely basis by employees during the normal course of business.  Additionally, internal controls over financial reporting may become inadequate in the future due to changes in the business environment.  

Under the supervision and with the participation of the principal executive officer and principal financial officer, PSNH conducted an evaluation of the effectiveness of internal controls over financial reporting based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).  Based on this evaluation under the framework in COSO, management concluded that internal controls over financial reporting were effective as of December 31, 2019.

February 26, 2020

70

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholder of Public Service Company of New Hampshire:

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of Public Service Company of New Hampshire and subsidiaries (the “Company”) as of December 31, 2019 and 2018, the related consolidated statements of income, comprehensive income, common stockholder’s equity, and cash flows, for each of the three years in the period ended December 31, 2019, and the related notes and the schedule listed in the Index at Item 15 of Part IV (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ Deloitte & Touche LLP

Hartford, Connecticut

February 26, 2020

We have served as the Company’s auditor since 2002.

71

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

	As of December 31,
(Thousands of Dollars)	2019			2018
ASSETS
Current Assets:
Cash	$	413		$	1,439
Receivables, Net	99,934			104,854
Accounts Receivable from Affiliated Companies	6,763			8,444
Unbilled Revenues	48,146			47,145
Taxes Receivable	1,497			25,913
Materials, Supplies and REC Inventory	24,957			37,504
Regulatory Assets	84,053			67,228
Special Deposits	32,513			47,498
Prepayments and Other Current Assets	17,934			17,564
Total Current Assets	316,210			357,589
Property, Plant and Equipment, Net	3,129,506			2,880,073
Deferred Debits and Other Assets:
Regulatory Assets	861,672			862,288
Other Long-Term Assets	43,270			27,406
Total Deferred Debits and Other Assets	904,942			889,694
Total Assets	$	4,350,658		$	4,127,356
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	27,000		$	57,000
Long-Term Debt – Current Portion	—			150,000
Rate Reduction Bonds – Current Portion	43,210			52,332
Accounts Payable	127,081			111,292
Accounts Payable to Affiliated Companies	37,946			26,029
Regulatory Liabilities	65,766			55,526
Accrued Interest	19,138			19,953
Other Current Liabilities	32,736			44,093
Total Current Liabilities	352,877			516,225
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	506,212			481,221
Regulatory Liabilities	413,381			428,069
Accrued Pension, SERP and PBOP	157,638			124,457
Other Long-Term Liabilities	37,075			36,339
Total Deferred Credits and Other Liabilities	1,114,306			1,070,086
Long-Term Debt	951,620			655,173
Rate Reduction Bonds	540,122			583,331
Common Stockholder's Equity:
Common Stock	—			—
Capital Surplus, Paid In	903,134			678,134
Retained Earnings	490,306			627,258
Accumulated Other Comprehensive Loss	(1,707		)	(2,851		)
Common Stockholder's Equity	1,391,733			1,302,541
Commitments and Contingencies (Note 13)
Total Liabilities and Capitalization	$	4,350,658		$	4,127,356

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

72

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

	For the Years Ended December 31,
(Thousands of Dollars)	2019		2018		2017
Operating Revenues	$	1,065,936	$	1,047,619	$	981,624
Operating Expenses:
Purchased Power, Fuel and Transmission	398,449		370,246		237,478
Operations and Maintenance	210,995		210,541		263,110
Depreciation	93,737		92,055		128,192
Amortization of Regulatory Assets/(Liabilities), Net	57,732		80,978		(16,577		)
Energy Efficiency Programs	25,982		20,105		13,788
Taxes Other Than Income Taxes	62,574		77,280		89,760
Total Operating Expenses	849,469		851,205		715,751
Operating Income	216,467		196,414		265,873
Interest Expense	60,666		60,634		51,007
Other Income, Net	19,222		27,672		9,805
Income Before Income Tax Expense	175,023		163,452		224,671
Income Tax Expense	40,975		47,576		88,675
Net Income	$	134,048	$	115,876	$	135,996

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

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

	For the Years Ended December 31,
(Thousands of Dollars)	2019		2018			2017
Net Income	$	134,048	$	115,876		$	135,996
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	1,075		1,104			1,162
Changes in Unrealized Gains/(Losses) on Marketable Securities	69		(33		)	(21		)
Other Comprehensive Income, Net of Tax	1,144		1,071			1,141
Comprehensive Income	$	135,192	$	116,947		$	137,137

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

73

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

	Common Stock			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount
Balance as of January 1, 2017	301	$	—	$	843,134		$	549,286		$	(5,063	)	$	1,387,357
Net Income							135,996						135,996
Dividends on Common Stock							(173,900		)				(173,900		)
Other Comprehensive Income										1,141			1,141
Balance as of December 31, 2017	301	—		843,134			511,382			(3,922		)	1,350,594
Net Income							115,876						115,876
Return of Capital				(530,000		)							(530,000		)
Capital Contributions from Eversource Parent				365,000									365,000
Other Comprehensive Income										1,071			1,071
Balance as of December 31, 2018	301	—		678,134			627,258			(2,851		)	1,302,541
Net Income							134,048						134,048
Dividends on Common Stock							(271,000		)				(271,000		)
Capital Contributions from Eversource Parent				225,000									225,000
Other Comprehensive Income										1,144			1,144
Balance as of December 31, 2019	301	$	—	$	903,134		$	490,306		$	(1,707	)	$	1,391,733

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

74

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

	For the Years Ended December 31,
(Thousands of Dollars)	2019			2018			2017
Operating Activities:
Net Income	$	134,048		$	115,876		$	135,996
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	93,737			92,055			128,192
Deferred Income Taxes	15,917			35,924			63,883
Uncollectible Expense	6,726			6,383			6,704
Pension, SERP and PBOP Expense, Net	417			754			1,368
Pension Contributions	(15,400		)	—			(800		)
Regulatory Underrecoveries, Net	(26,288		)	(27,264		)	(30,788		)
Amortization of Regulatory Assets/(Liabilities), Net	57,732			80,978			(16,577		)
Other	(28,228		)	(15,363		)	(16,813		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(210		)	(19,307		)	(22,055		)
Materials, Supplies and REC Inventory	1,902			16,928			5,519
Taxes Receivable/Accrued, Net	25,374			(19,970		)	339
Accounts Payable	12,281			(10,147		)	29,453
Other Current Assets and Liabilities, Net	(3,573		)	3,028			16,463
Net Cash Flows Provided by Operating Activities	274,435			259,875			300,884
Investing Activities:
Investments in Property, Plant and Equipment	(308,993		)	(323,910		)	(312,720		)
Proceeds from the Sale of Generation Assets	—			193,924			—
Proceeds from the Sale of Property	—			4,782			—
Other Investing Activities	1,023			437			199
Net Cash Flows Used in Investing Activities	(307,970		)	(124,767		)	(312,521		)
Financing Activities:
Cash Dividends on Common Stock	(271,000		)	(150,000		)	(23,900		)
(Decrease)/Increase in Notes Payable to Eversource Parent	(30,000		)	(205,900		)	102,000
Issuance of Long-Term Debt	300,000			—			—
Retirement of Long-Term Debt	(150,000		)	(199,250		)	(70,000		)
(Repayment)/Issuance of Rate Reduction Bonds	(52,332		)	635,663			—
Return of Capital	—			(530,000		)	—
Capital Contributions from Eversource Parent	225,000			365,000			—
Other Financing Activities	(4,168		)	(89		)	(225		)
Net Cash Flows Provided by/(Used in) Financing Activities	17,500			(84,576		)	7,875
Net (Decrease)/Increase in Cash and Restricted Cash	(16,035		)	50,532			(3,762		)
Cash and Restricted Cash - Beginning of Year	52,723			2,191			5,953
Cash and Restricted Cash - End of Year	$	36,688		$	52,723		$	2,191

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

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EVERSOURCE ENERGY AND SUBSIDIARIES

THE CONNECTICUT LIGHT AND POWER COMPANY

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

COMBINED NOTES TO FINANCIAL STATEMENTS

Refer to the Glossary of Terms included in this combined Annual Report on Form 10-K for abbreviations and acronyms used throughout the combined notes to the financial statements.

1.     SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

A.     About Eversource, CL&P, NSTAR Electric and PSNH

Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business.  Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), Yankee Gas and NSTAR Gas (natural gas utilities) and Aquarion (water utilities).  Eversource provides energy delivery and/or water service to approximately four million electric, natural gas and water customers through eight regulated utilities in Connecticut, Massachusetts and New Hampshire.  

Eversource, CL&P, NSTAR Electric and PSNH are reporting companies under the Securities Exchange Act of 1934.  Eversource Energy is a public utility holding company under the Public Utility Holding Company Act of 2005.  Arrangements among the regulated electric companies and other Eversource companies, outside agencies and other utilities covering interconnections, interchange of electric power and sales of utility property are subject to regulation by the FERC. Eversource's regulated companies are subject to regulation of rates, accounting and other matters by the FERC and/or applicable state regulatory commissions (the PURA for CL&P, Yankee Gas and Aquarion, the DPU for NSTAR Electric, NSTAR Gas and Aquarion, and the NHPUC for PSNH and Aquarion).

CL&P, NSTAR Electric and PSNH furnish franchised retail electric service in Connecticut, Massachusetts and New Hampshire.  Yankee Gas and NSTAR Gas are engaged in the distribution and sale of natural gas to customers within Connecticut and Massachusetts, respectively.  Aquarion is engaged in the collection, treatment and distribution of water in Connecticut, Massachusetts and New Hampshire. CL&P, NSTAR Electric and PSNH's results include the operations of their respective distribution and transmission businesses. The distribution business also includes the results of NSTAR Electric's solar power facilities and PSNH's generation facilities prior to sale in 2018. PSNH completed the sales of all its thermal and hydroelectric generation assets in 2018. See Note 14, "Generation Asset Sale," for further information.

Eversource Service, Eversource's service company, and several wholly-owned real estate subsidiaries of Eversource, provide support services to Eversource, including its regulated companies.

B.     Basis of Presentation

The consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries. Intercompany transactions have been eliminated in consolidation.  The accompanying consolidated financial statements of Eversource, NSTAR Electric and PSNH and the financial statements of CL&P are herein collectively referred to as the "financial statements."  

The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent liabilities as of 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.

Eversource consolidates the operations of CYAPC and YAEC, both of which are inactive regional nuclear generation companies engaged in the long-term storage of their spent nuclear fuel. Eversource consolidates CYAPC and YAEC because CL&P's, NSTAR Electric's and PSNH's combined ownership and voting interests in each of these entities is greater than 50 percent.  Intercompany transactions between CL&P, NSTAR Electric, PSNH and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.  

Eversource's consolidated financial information includes the results of Aquarion and its subsidiaries beginning from the date of the acquisition on December 4, 2017.

Eversource holds several equity ownership interests that are not consolidated and are accounted for under the equity method.

In accordance with accounting guidance on noncontrolling interests in consolidated financial statements, the Preferred Stock of CL&P and the Preferred Stock of NSTAR Electric, which are not owned by Eversource or its consolidated subsidiaries and are not subject to mandatory redemption, have been presented as noncontrolling interests in the financial statements of Eversource.  The Preferred Stock of CL&P and the Preferred Stock of NSTAR Electric are considered to be temporary equity and have been classified between liabilities and permanent shareholders' equity on the balance sheets of Eversource, CL&P and NSTAR Electric due to a provision in the preferred stock agreements of both CL&P and NSTAR Electric that grant preferred stockholders the right to elect a majority of the CL&P and NSTAR Electric Boards of Directors, respectively, should certain conditions exist, such as if preferred dividends are in arrears for a specified amount of time.  The Net Income reported in the statements of income and cash flows represents net income prior to apportionment to noncontrolling interests, which is represented by dividends on preferred stock of CL&P and NSTAR Electric.

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Eversource's utility subsidiaries' electric, natural gas and water distribution and transmission businesses are subject to rate-regulation that is based on cost recovery and meets the criteria for application of accounting guidance for entities with rate-regulated operations, which considers the effect of regulation on the differences in the timing of the recognition of certain revenues and expenses from those of other businesses and industries.  See Note 2, "Regulatory Accounting," for further information.

Certain reclassifications of prior year data were made in the accompanying financial statements to conform to the current year presentation.

The Eversource and PSNH 2018 statements of cash flows, the 2018 supplemental cash flow information footnote, and the 2018 segment footnote were revised to correct an error in the presentation of non-cash capital additions.  The impact of this revision on the statement of cash flows is an increase to operating cash inflows in Accounts Payable of $46.6 million and a corresponding increase to investing cash outflows in Investments in Property, Plant and Equipment for the year ended December 31, 2018.  This revision is not deemed material, individually or in the aggregate, to the previously issued financial statements.

As of both December 31, 2019 and 2018, Eversource's carrying amount of goodwill was $4.43 billion. Eversource performs an assessment for possible impairment of its goodwill at least annually.  Eversource completed its annual goodwill impairment test for each of its reporting units as of October 1, 2019 and determined that no impairment exists.  See Note 25B, "Acquisition of Aquarion and Goodwill - Goodwill," for further information.

C.     Accounting Standards

Accounting Standards Issued but Not Yet Effective: In June 2016, the FASB issued Accounting Standards Update (“ASU”) 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. Under the new guidance, immediate recognition of credit losses expected over the life of a financial instrument is required. The standard is effective January 1, 2020. The Company assessed the impacts of this standard on the accounting for credit losses on its financial instruments, including accounts receivable, and does not expect a material impact on the financial statements of Eversource, CL&P, NSTAR Electric or PSNH.

In December 2019, the FASB issued ASU 2019-12, Income Taxes (Topic 740) - Simplifying the Accounting for Income Taxes, which eliminates certain exceptions to the general principles of current income tax guidance in ASC 740, Income Taxes, and simplifies and improves consistency in application of that income tax guidance through clarifications of, and amendments to, ASC 740. The guidance is effective in the first quarter of 2021.  The Company is evaluating the impact of this standard on the financial statements of Eversource, CL&P, NSTAR Electric and PSNH.

Accounting Standards Recently Adopted: On January 1, 2019, the Company adopted ASU 2016-02, Leases (Topic 842), which amended existing lease accounting guidance. The Company applied the Topic 842 lease criteria to new leases and lease renewals entered into effective on or after January 1, 2019.  The ASU required balance sheet recognition of leases deemed to be operating leases as well as additional disclosure requirements.  The recognition, measurement and presentation of expenses and cash flows were not significantly changed.

The Company utilized the modified retrospective transition method allowed in ASU 2018-11, Leases (Topic 842) - Targeted Improvements, which allowed the Company to adopt the new leases standard as of January 1, 2019, with prior periods presented in the financial statements continuing to follow existing lease accounting guidance under Topic 840 (Leases) in the accounting literature.  Implementation of ASU 2018-11 had no effect on retained earnings, and the requirements of the new lease standard (Topic 842) are reflected in the 2019 financial statements and footnotes.

The Company elected the practical expedient package whereby it did not need to reassess whether or not an existing contract is or contains a lease or whether a lease is an operating or capital lease, and it did not need to reassess initial direct costs for leases. Election of this practical expedient allowed us to carry forward our historical lease classifications. The Company elected the practical expedient to not reevaluate land easements existing at adoption if they were not previously accounted for as leases. The Company also elected to use the discount rate as of the January 1, 2019 implementation date to discount its operating lease liabilities. The Company did not elect the hindsight practical expedient to determine the lease term for existing leases.

The Company determined the impact the ASUs had on its financial statements by reviewing its lease population and identifying lease data needed for the disclosure requirements. The Company implemented a new lease accounting system in 2019 to ensure ongoing compliance with the ASU’s requirements. Adoption of the new standard resulted in the recording of operating lease liabilities and right-of-use assets on the balance sheet upon transition at January 1, 2019 of $58.0 million at Eversource, $25.3 million at NSTAR Electric, $0.6 million at CL&P, and $0.6 million at PSNH. Implementation of the new guidance did not have an impact on each company’s results of operations or cash flows.

D.     Impairment of Northern Pass Transmission

Northern Pass was Eversource's planned 1,090 MW HVDC transmission line that would have interconnected from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. As a result of a final decision received on July 19, 2019 from the New Hampshire Supreme Court, whereby the court denied Northern Pass’ appeal and affirmed the NHSEC’s denial of Northern Pass’ siting application on NPT, Eversource concluded that construction of NPT was no longer probable and that there was no constructive path forward for the project. Eversource terminated the project and permanently abandoned any further development.  As a result, substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired.

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Based on the conclusion that the construction of Northern Pass was no longer probable, Eversource recorded an impairment charge in 2019 for all of the project costs associated with Northern Pass, which were primarily engineering design, siting, permitting and legal costs, along with appropriate allowances for funds used during construction, and recognized a receivable for certain cost reimbursement agreements. Additionally, Eversource recorded an impairment charge associated with the land acquired to construct Northern Pass in order to recognize the land at its estimated fair value based on assessed values and transaction costs. In total, this resulted in a pre-tax impairment charge of $239.6 million within Operating Income on the statement of income for the year ended December 31, 2019, and was reflected in the Electric Transmission segment. The after-tax impact of the impairment charge was $204.4 million, or $0.64 per share, after giving effect to the estimated fair value of the related land, reimbursement agreements, and the impact of expected income tax benefits associated with the impairment charge. As a result of the decision to terminate the NPT project and permanently abandon any further development, Eversource does not expect any future cash expenditures associated with this project.

E.     Cash

Cash includes cash on hand.  At the end of each reporting period, any overdraft amounts are reclassified from Cash to Accounts Payable on the balance sheets.

F.     Provision for Uncollectible Accounts

Eversource, including CL&P, NSTAR Electric and PSNH, presents its receivables at estimated net realizable value by maintaining a provision for uncollectible accounts.  This provision is determined based upon a variety of judgments and factors, including the application of an estimated uncollectible percentage to each receivable aging category.  The estimate is based upon historical collection and write-off experience and management's assessment of collectability from customers.  Management continuously assesses the collectability of receivables and adjusts collectability estimates based on actual experience.  Receivable balances are written off against the provision for uncollectible accounts when the customer accounts are terminated and these balances are deemed to be uncollectible.

The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively.  The DPU allows NSTAR Electric and NSTAR Gas to recover in rates, amounts associated with certain uncollectible hardship accounts receivable.  These uncollectible hardship customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets.  

The total provision for uncollectible accounts is included in Receivables, Net on the balance sheets. The provision for uncollectible hardship accounts is included in the total uncollectible provision balance. The provision balances were as follows:

	Total Provision for Uncollectible Accounts				Provision for Uncollectible Hardship Accounts
	As of December 31,				As of December 31,
(Millions of Dollars)	2019		2018		2019		2018
Eversource	$	224.8	$	212.7	$	143.3	$	131.5
CL&P	97.3		88.0		80.1		71.9
NSTAR Electric	75.4		74.5		43.9		42.5
PSNH	10.5		11.1		—		—

Uncollectible expense associated with customers' accounts receivable included in Operations and Maintenance expense on the statements of income was as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource	$	63.4	$	61.3	$	44.5
CL&P	15.9		15.8		5.3
NSTAR Electric	25.1		22.3		21.3
PSNH	6.7		6.4		6.7

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G.    Transfer of Energy Efficiency Loans

In 2018, CL&P transferred $41.3 million of its energy efficiency customer loan portfolio to two outside lenders in order to make additional loans to customers.  CL&P remains the servicer of the loans and will transmit customer payments to the lenders.  Under a three-year agreement with the lenders, additional energy efficiency loans will also be transferred with a maximum amount outstanding under this program of $55 million.  The transaction did not qualify as a sale for accounting purposes, and the amounts of the loans are included in Accounts Receivable, Net and Other Long-Term Assets, and are offset by Other Current Liabilities and Other Long-Term Liabilities on CL&P’s balance sheet. The current and long-term portions totaled $16.5 million and $18.2 million, respectively, as of December 31, 2019, and $18.5 million and $22.8 million, respectively, as of December 31, 2018.

H.     Fuel, Materials, Supplies and REC Inventory

Fuel, Materials, Supplies and REC Inventory include natural gas inventory, materials and supplies purchased primarily for construction or operation and maintenance purposes, and RECs.  Inventory is valued at the lower of cost or net realizable value. RECs are purchased from suppliers of renewable sources of generation and are used to meet state mandated Renewable Portfolio Standards requirements.  The carrying amounts of fuel, materials and supplies, and RECs, which are included in Current Assets on the balance sheets, were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Fuel	$	26.7	$	—	$	—	$	—	$	33.1	$	—	$	—	$	—
Materials and Supplies	132.9		50.7		54.7		18.5		126.1		44.5		48.6		24.3
RECs	75.9		—		69.4		6.5		78.8		—		65.6		13.2
Total	$	235.5	$	50.7	$	124.1	$	25.0	$	238.0	$	44.5	$	114.2	$	37.5

I.     Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" (normal) and to the marketable securities held in trusts.  Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill, long-lived assets and AROs. We also applied this guidance in the valuation of our basis differences in our equity method offshore wind investments (see Note 6, "Investments in Unconsolidated Affiliates," for further information). The fair value measurement guidance was also applied in estimating the fair value of preferred stock, long-term debt and RRBs.

Fair Value Hierarchy:  In measuring fair value, Eversource uses observable market data when available in order to minimize the use of unobservable inputs.  Inputs used in fair value measurements are categorized into three fair value hierarchy levels for disclosure purposes.  The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement.  Eversource evaluates the classification of assets and liabilities measured at fair value on a quarterly basis, and Eversource's policy is to recognize transfers between levels of the fair value hierarchy as of the end of the reporting period.  The three levels of the fair value hierarchy are described below:

Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  

Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable.

Level 3 - Quoted market prices are not available.  Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable.  Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products.  

Uncategorized - Investments that are measured at net asset value are not categorized within the fair value hierarchy.

Determination of Fair Value:  The valuation techniques and inputs used in Eversource's fair value measurements are described in Note 4, "Derivative Instruments," Note 5, "Marketable Securities," Note 6, "Investments in Unconsolidated Affiliates," Note 7, "Asset Retirement Obligations," Note 11A, "Employee Benefits – Pension Benefits and Postretirement Benefits Other Than Pension," Note 16, "Fair Value of Financial Instruments" and Note 25B, "Acquisition of Aquarion and Goodwill - Goodwill" to the financial statements.

J.     Derivative Accounting

Many of the electric and natural gas companies' contracts for the purchase and sale of energy or energy-related products are derivatives.  The accounting treatment for energy contracts entered into varies and depends on the intended use of the particular contract and on whether or not the contract is a derivative.  

The application of derivative accounting is complex and requires management judgment in the following respects: identification of derivatives and embedded derivatives, election and designation of a contract as normal, and determination of the fair value of derivative contracts.  All of these judgments can have a significant impact on the financial statements.  The judgment applied in the election of a contract as normal (and resulting accrual accounting) includes the conclusion that it is probable at the inception of the contract and throughout its term that it will result in physical delivery of the underlying product and that the quantities will be used or sold by the business in the normal course of business.  If facts and circumstances change and management can no longer support this conclusion, then a contract cannot be considered normal, accrual accounting is terminated, and fair value accounting is applied prospectively.  

The fair value of derivative contracts is based upon the contract terms and conditions and the underlying market price or fair value per unit.  When quantities are not specified in the contract, the Company determines whether the contract has a determinable quantity by using amounts referenced in default provisions and other relevant sections of the contract.  The fair value of derivative assets and liabilities with the same counterparty are offset and recorded as a net derivative asset or liability on the balance sheets.  

Regulatory assets or regulatory liabilities are recorded to offset the fair values of derivative contracts related to energy and energy-related products, as contract settlements are recovered from, or refunded to, customers in future rates. All changes in the fair value of derivative contracts are recorded as regulatory assets or liabilities and do not impact net income.

For further information regarding derivative contracts, see Note 4, "Derivative Instruments," to the financial statements.

K.     Operating Expenses

Costs related to fuel and natural gas included in Purchased Power, Fuel and Transmission on the statements of income were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource - Natural Gas and Fuel	$	462.1	$	442.6	$	432.5
PSNH - Fuel	—		7.9		43.4

PSNH completed the sale of its generation assets in 2018. See Note 14, "Generation Asset Sale," for further information.

L.     Allowance for Funds Used During Construction

AFUDC represents the cost of borrowed and equity funds used to finance construction and is included in the cost of the electric, natural gas and water companies' utility plant on the balance sheet.  The portion of AFUDC attributable to borrowed funds is recorded as a reduction of Interest Expense, and the AFUDC related to equity funds is recorded as Other Income, Net on the statements of income.  AFUDC costs are recovered from customers over the service life of the related plant in the form of increased revenue collected as a result of higher depreciation expense.

The average AFUDC rate is based on a FERC-prescribed formula using the cost of a company's short-term financings and capitalization (preferred stock, long-term debt and common equity), as appropriate.  The average rate is applied to average eligible CWIP amounts to calculate AFUDC.

AFUDC costs and the weighted-average AFUDC rates were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars, except percentages)	2019			2018			2017
Borrowed Funds	$	25.6		$	19.7		$	12.5
Equity Funds	45.0			44.0			34.4
Total AFUDC	$	70.6		$	63.7		$	46.9
Average AFUDC Rate	5.4		%	4.9		%	5.1		%

	For the Years Ended December 31,
	2019									2018									2017
(Millions of Dollars, except percentages)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Borrowed Funds	$	7.1		$	10.4		$	2.8		$	6.3		$	7.8		$	1.3		$	5.1		$	4.8		$	0.7
Equity Funds	13.2			19.8			3.4			12.2			15.6			—			12.1			10.2			—
Total AFUDC	$	20.3		$	30.2		$	6.2		$	18.5		$	23.4		$	1.3		$	17.2		$	15.0		$	0.7
Average AFUDC Rate	6.3		%	5.7		%	4.6		%	5.8		%	5.0		%	0.7		%	6.2		%	5.0		%	0.7		%

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M.     Other Income, Net

The components of Other Income, Net on the statements of income were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018			2017
Pension, SERP and PBOP Non-Service Income Components	$	31.3	$	60.8		$	29.9
AFUDC Equity	45.0		44.0			34.4
Equity in Earnings of Unconsolidated Affiliates (1)	42.2		3.8			27.4
Investment Income/(Loss)	0.8		(4.0		)	7.5
Interest Income (2)	12.8		18.1			8.3
Gains on Sales of Property	0.3		5.1			—
Other	0.4		0.6			0.4
Total Other Income, Net	$	132.8	$	128.4		$	107.9

	For the Years Ended December 31,
	2019								2018									2017
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH		CL&P			NSTAR Electric			PSNH			CL&P		NSTAR Electric		PSNH
Pension, SERP and PBOP Non-Service   Income Components	$	0.5		$	23.5		$	4.9	$	9.5		$	36.0		$	9.9		$	1.8	$	19.2	$	5.9
AFUDC Equity	13.2			19.8			3.4		12.2			15.6			—			12.1		10.2		—
Equity in Earnings of Unconsolidated Affiliates	0.1			0.7			—		0.1			0.7			—			—		0.3		—
Investment Income/(Loss)	2.3			(0.4		)	0.3		(3.0		)	(0.5		)	(0.8		)	4.5		2.6		1.6
Interest Income (2)	1.5			0.7			10.5		3.7			0.8			14.1			4.6		1.8		2.2
Gains on Sales of Property	—			0.1			—		—			0.5			4.4			—		—		—
Other	(0.1		)	0.2			0.1		0.2			—			0.1			—		—		0.1
Total Other Income, Net	$	17.5		$	44.6		$	19.2	$	22.7		$	53.1		$	27.7		$	23.0	$	34.1	$	9.8

⁽¹⁾  Equity in earnings of unconsolidated affiliates includes an other-than-temporary impairment of $32.9 million of the Access Northeast project investment for the year ended December 31, 2018. See Note 6, "Investments in Unconsolidated Affiliates," for further information. Equity in earnings includes $20.4 million, $17.6 million and $9.7 million of pre-tax unrealized gains for the years ended December 31, 2019, 2018 and 2017, respectively, associated with an equity method investment in a renewable energy fund.

⁽²⁾ For the years ended December 31, 2019 and 2018, PSNH recognized $6.3 million and $8.7 million, respectively, of interest income for the equity return component of carrying charges on storm costs approved in 2019 and 2018. See Note 2, "Regulatory Accounting," for further information.

N.     Other Taxes

Eversource's companies that serve customers in Connecticut collect gross receipts taxes levied by the state of Connecticut from their customers. These gross receipts taxes are recorded separately with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the statements of income as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource	$	163.1	$	161.9	$	157.4
CL&P	141.1		141.4		137.5

As agents for state and local governments, Eversource's companies that serve customers in Connecticut and Massachusetts collect certain sales taxes that are recorded on a net basis with no impact on the statements of income.  

Separate from above were amounts recorded as Taxes Other Than Income Taxes related to the remittance to the State of Connecticut of energy efficiency funds collected from customers in Operating Revenues. These amounts were $21.4 million and $46.8 million in 2019 and 2018, respectively. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. These amounts were recorded separately, with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the Eversource and CL&P statements of income.

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O.     Supplemental Cash Flow Information

Eversource (Millions of Dollars)	As of and For the Years Ended December 31,
	2019		2018		2017
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	$	532.4	$	503.2	$	419.1
Income Taxes	56.0		158.8		30.8
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of) (1)	379.4		389.3		379.5

	As of and For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	$	144.6	$	121.9	$	56.9	$	149.7	$	122.1	$	40.5	$	144.6	$	124.6	$	45.9
Income Taxes	80.6		77.9		3.4		66.1		120.0		27.3		68.8		95.5		26.1
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of) (1)	111.3		116.4		49.9		106.1		116.5		35.1		132.5		116.5		44.4

⁽¹⁾ See Note 1B, "Summary of Significant Accounting Policies - Basis of Presentation," for information regarding the correction of non-cash capital additions at Eversource and PSNH reported as of December 31, 2018.

Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan. The issuance of treasury shares represents a non-cash transaction, as the treasury shares were used to fulfill Eversource's obligations that require the issuance of common shares.

The following table reconciles cash as reported on the balance sheets to the cash and restricted cash balance as reported on the statements of cash flows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Cash as reported on the Balance Sheets	$	15.4	$	—	$	0.1	$	0.4	$	108.1	$	87.7	$	1.6	$	1.4
Restricted cash included in:
Special Deposits	52.5		4.6		6.2		32.5		72.1		3.5		13.0		47.5
Marketable Securities	46.0		0.4		—		0.6		25.9		0.4		0.1		0.6
Other Long-Term Assets	3.2		—		—		3.2		3.2		—		—		3.2
Cash and Restricted Cash reported on the     Statements of Cash Flows	$	117.1	$	5.0	$	6.3	$	36.7	$	209.3	$	91.6	$	14.7	$	52.7

Special Deposits represent cash collections related to the PSNH RRB customer charges that are held in trust and required ISO-NE cash deposits, and are included in Current Assets on the balance sheets. Restricted cash included in Marketable Securities represents money market funds held in trusts to fund certain non-qualified executive benefits and restricted trusts to fund CYAPC and YAEC's spent nuclear fuel storage obligations.

P.     Related Parties

Eversource Service, Eversource's service company, provides centralized accounting, administrative, engineering, financial, information technology, legal, operational, planning, purchasing, tax, and other services to Eversource's companies.  The Rocky River Realty Company, Renewable Properties, Inc. and Properties, Inc., three other Eversource subsidiaries, construct, acquire or lease some of the property and facilities used by Eversource's companies.

As of both December 31, 2019 and 2018, CL&P, NSTAR Electric and PSNH had long-term receivables from Eversource Service in the amounts of $25.0 million, $5.5 million and $3.8 million, respectively, which were included in Other Long-Term Assets on the balance sheets. These amounts related to the funding of investments held in trust by Eversource Service in connection with certain postretirement benefits for CL&P, NSTAR Electric and PSNH employees and have been eliminated in consolidation on the Eversource financial statements.  

Included in the CL&P, NSTAR Electric and PSNH balance sheets as of December 31, 2019 and 2018 were Accounts Receivable from Affiliated Companies and Accounts Payable to Affiliated Companies relating to transactions between CL&P, NSTAR Electric and PSNH and other subsidiaries that are wholly-owned by Eversource.  These amounts have been eliminated in consolidation on the Eversource financial statements.

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Q.     Acquisition of Assets of Columbia Gas of Massachusetts

On February 26, 2020, Eversource and NiSource entered into an asset purchase agreement (the Agreement) pursuant to which Eversource would acquire the assets that comprise NiSource’s local gas distribution business in Massachusetts, which is doing business as Columbia Gas of Massachusetts (CMA). The purchase price of $1.1 billion includes a target working capital amount that would be adjusted to reflect actual working capital as of the closing date. The acquisition and resulting rate plan both require DPU and other approvals.

The liabilities to be assumed by Eversource under the Agreement specifically exclude any liabilities (past or future) arising out of or related to the fires and explosions that occurred on September 13, 2018 in Lawrence, Andover and North Andover, Massachusetts related to the delivery of natural gas by CMA, including certain subsequent events, all as described and in the DPU's Order on Scope dated December 23, 2019 (D.P.U. 19-141) (the Greater Lawrence Incident or GLI), and any further emergency events prior to the closing of the acquisition related to the restoration and reconstruction with respect to the GLI, including any losses arising out of or related to any litigation, demand, cause of action, claim, suit, investigation, proceeding, indemnification agreements or rights.

2.     REGULATORY ACCOUNTING

Eversource's utility companies are subject to rate regulation that is based on cost recovery and meets the criteria for application of accounting guidance for rate-regulated operations, which considers the effect of regulation on the timing of the recognition of certain revenues and expenses. The regulated companies' financial statements reflect the effects of the rate-making process.  The rates charged to the customers of Eversource's regulated companies are designed to collect each company's costs to provide service, plus a return on investment.  

The application of accounting guidance for rate-regulated enterprises results in recording regulatory assets and liabilities.  Regulatory assets represent the deferral of incurred costs that are probable of future recovery in customer rates.  Regulatory assets are amortized as the incurred costs are recovered through customer rates.  Regulatory liabilities represent either revenues received from customers to fund expected costs that have not yet been incurred or probable future refunds to customers.

Management believes it is probable that each of the regulated companies will recover its respective investments in long-lived assets, including regulatory assets.  If management were to determine that it could no longer apply the accounting guidance applicable to rate-regulated enterprises to any of the regulated companies' operations, or if management could not conclude it is probable that costs would be recovered from customers in future rates, the costs would be charged to net income in the period in which the determination is made.

Regulatory Assets:  The components of regulatory assets were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Benefit Costs	$	2,382.9	$	539.0	$	629.8	$	218.2	$	1,914.8	$	424.7	$	544.4	$	169.6
Income Taxes, Net	725.8		458.8		108.0		12.8		728.6		454.4		105.9		8.3
Securitized Stranded Costs	565.3		—		—		565.3		608.4		—		—		608.4
Storm Restoration Costs, Net	540.6		274.6		200.6		65.4		576.0		302.6		212.9		60.5
Regulatory Tracker Mechanisms	411.5		78.3		207.1		65.8		316.0		33.2		169.1		67.3
Derivative Liabilities	334.5		329.2		—		—		356.5		356.5		—		—
Goodwill-related	331.5		—		284.6		—		348.4		—		299.1		—
Asset Retirement Obligations	97.2		30.8		50.3		3.6		89.2		32.3		42.2		3.3
Other Regulatory Assets	125.4		25.2		55.2		14.7		208.0		27.0		64.6		12.1
Total Regulatory Assets	5,514.7		1,735.9		1,535.6		945.8		5,145.9		1,630.7		1,438.2		929.5
Less:  Current Portion	651.1		178.6		285.6		84.1		514.8		125.2		241.7		67.2
Total Long-Term Regulatory Assets	$	4,863.6	$	1,557.3	$	1,250.0	$	861.7	$	4,631.1	$	1,505.5	$	1,196.5	$	862.3

Benefit Costs:  Eversource's Pension, SERP and PBOP Plans are accounted for in accordance with accounting guidance on defined benefit pension and other PBOP plans.  The liability (or asset) recorded by the regulated companies to recognize the funded status of their retiree benefit plans is offset by a regulatory asset (or offset by a regulatory liability in the case of a benefit plan asset) in lieu of a charge to Accumulated Other Comprehensive Income/(Loss), reflecting ultimate recovery from customers through rates.  The regulatory asset (or regulatory liability) is amortized as the actuarial gains and losses and prior service cost are amortized to net periodic benefit cost for the pension and PBOP plans.  All amounts are remeasured annually.  Regulatory accounting is also applied to the portions of Eversource's service company costs that support the regulated companies, as these amounts are also recoverable.  As these regulatory assets or regulatory liabilities do not represent a cash outlay for the regulated companies, no carrying charge is recovered from customers. See Note 11A, "Employee Benefits - Pensions and Postretirement Benefits Other Than Pension," for further information on regulatory benefit plan amounts recognized and amortized during the year.

CL&P, NSTAR Electric and PSNH recover benefit costs related to their distribution and transmission operations from customers in rates as allowed by their applicable regulatory commissions.  NSTAR Electric recovers qualified pension and PBOP expenses related to its distribution operations through a rate reconciling mechanism that fully tracks the change in net pension and PBOP expenses each year.  

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Income Taxes, Net:  The tax effect of temporary book-tax differences (differences between the periods in which transactions affect income in the financial statements and the periods in which they affect the determination of taxable income, including those differences relating to uncertain tax positions) is accounted for in accordance with the rate-making treatment of the applicable regulatory commissions and accounting guidance for income taxes.  Differences in income taxes between the accounting guidance and the rate-making treatment of the applicable regulatory commissions are recorded as regulatory assets.  As these assets are offset by deferred income tax liabilities, no carrying charge is collected.  The amortization period of these assets varies depending on the nature and/or remaining life of the underlying assets and liabilities.  For further information regarding income taxes, see Note 12, "Income Taxes," to the financial statements.  

Securitized Stranded Costs: In 2018, a subsidiary of PSNH issued $635.7 million of securitized RRBs to finance PSNH's unrecovered remaining costs associated with the divestiture of its generation assets. Securitized regulatory assets, which are not earning an equity return, are being recovered over the amortization period of the associated RRBs. The PSNH RRBs are expected to be repaid by February 1, 2033. For further information, see Note 10, "Rate Reduction Bonds and Variable Interest Entities."

Storm Restoration Costs, Net: The storm restoration cost deferrals relate to costs incurred for storm events at CL&P, NSTAR Electric and PSNH that each company expects to recover from customers.  A storm must meet certain criteria to qualify for deferral and recovery with the criteria specific to each state jurisdiction and utility company. Once a storm qualifies for recovery, all qualifying expenses incurred during storm restoration efforts are deferred and recovered from customers. Costs for storms that do not meet the specific criteria are expensed as incurred. In addition to storm restoration costs, CL&P and PSNH are each allowed to recover pre-staging storm costs. Management believes storm restoration costs deferred were prudently incurred and meet the criteria for specific cost recovery in Connecticut, Massachusetts and New Hampshire, and that recovery from customers is probable through the applicable regulatory recovery processes. Each electric utility company either recovers a carrying charge on its deferred storm restoration cost regulatory asset balance or the regulatory asset balance is included in rate base.

In 2019, several significant storms caused extensive damage to our electric distribution systems and customer outages. These storms resulted in deferred storm restoration costs of approximately $126 million ($62 million for CL&P, $48 million for NSTAR Electric, and $16 million for PSNH), which were reflected in Storm Restoration Costs, Net in the table above as of December 31, 2019.

Storm Filings: On November 16, 2018, CL&P filed for recovery of $153 million of storm costs incurred from October 2017 through May 2018, with recovery over six years.  Through the course of the proceeding, CL&P updated its request to $145.5 million to reflect final invoicing and capitalization amounts. On April 17, 2019, PURA authorized recovery of $141.0 million as part of storm cost recovery and the remainder to be recorded to plant or other balance sheet accounts. CL&P began recovery of the $141.0 million in distribution rates effective May 1, 2019.

On March 26, 2019, the NHPUC approved the recovery of $38.1 million, plus carrying charges, of storm costs incurred from December 2013 through April 2016 and the transfer of funding from PSNH’s major storm reserve to recover those costs. The costs of these storms (excluding the equity return component of the carrying charges) were deferred as regulatory assets, and the funding reserve collected from customers was accrued as a regulatory liability. As a result of the duration of time between incurring storm costs in December 2013 through April 2016 and final approval from the NHPUC in 2019, PSNH recognized $5.2 million (pre-tax) for the equity return component of the carrying charges within Other Income, Net on the statement of income in 2019, which has been collected from customers. Also included in the March 26, 2019 NHPUC approval is a prospective requirement for PSNH to annually net its storm funding reserve collected from customers against deferred storm costs.

In addition, on June 27, 2019, the NHPUC approved a temporary rate settlement that allowed PSNH to recover approximately $68.5 million in unrecovered storm costs over a five-year period beginning August 1, 2019, with debt carrying charges.

Regulatory Tracker Mechanisms:  The regulated companies' approved rates are designed to recover costs incurred to provide service to customers. The regulated companies recover certain of their costs on a fully-reconciling basis through regulatory commission-approved tracking mechanisms. The differences between the costs incurred (or the rate recovery allowed) and the actual revenues are recorded as regulatory assets (for undercollections) or as regulatory liabilities (for overcollections) to be included in future customer rates each year.  Carrying charges are recovered in rates on all material regulatory tracker mechanisms.

CL&P, NSTAR Electric and PSNH each recover, on a fully reconciling basis, the costs associated with the procurement of energy, transmission related costs from FERC-approved transmission tariffs, energy efficiency programs, low income assistance programs, certain uncollectible accounts receivable for hardship customers, and restructuring and stranded costs as a result of deregulation (including securitized RRB charges), and additionally for the Massachusetts utilities, pension and PBOP benefits and net metering for distributed generation. Energy procurement costs at NSTAR Electric include the costs related to its solar power facilities.

CL&P, NSTAR Electric, Yankee Gas and NSTAR Gas each have a regulatory commission approved revenue decoupling mechanism. Distribution revenues are decoupled from customer sales volumes, where applicable, which breaks the relationship between sales volumes and revenues.  Each company reconciles its annual base distribution rate recovery amount to the pre-established levels of baseline distribution delivery service revenues. Any difference between the allowed level of distribution revenue and the actual amount realized during a 12-month period is adjusted through rates in the following period. 

Derivative Liabilities:  Regulatory assets are recorded as an offset to derivative liabilities and relate to the fair value of contracts used to purchase energy and energy-related products that will be recovered from customers in future rates.  These assets are excluded from rate base and are being recovered as the actual settlements occur over the duration of the contracts.  See Note 4, "Derivative Instruments," to the financial statements for further information on these contracts.

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Goodwill-related:  The goodwill regulatory asset originated from a 1999 transaction, and the DPU allowed its recovery in NSTAR Electric and NSTAR Gas rates.  This regulatory asset is currently being amortized and recovered from customers in rates without a carrying charge over a 40-year period, and as of December 31, 2019, there were 20 years of amortization remaining.

Asset Retirement Obligations: The costs associated with the depreciation of the regulated companies' ARO assets and accretion of the ARO liabilities are recorded as regulatory assets in accordance with regulatory accounting guidance. The regulated companies' ARO assets, regulatory assets and liabilities offset and are excluded from rate base. These costs are being recovered over the life of the underlying property, plant and equipment.

Other Regulatory Assets:  Other Regulatory Assets primarily include contractual obligations associated with the spent nuclear fuel storage costs of the CYAPC, YAEC and MYAPC decommissioned nuclear power facilities, environmental remediation costs, losses associated with the reacquisition or redemption of long-term debt, certain uncollectible accounts receivable for hardship customers, certain merger-related costs allowed for recovery, water tank painting costs, and various other items.

Regulatory Costs in Long-Term Assets:  Eversource's regulated companies had $146.0 million (including $51.8 million for CL&P, $55.7 million for NSTAR Electric and $18.0 million for PSNH) and $122.9 million (including $42.1 million for CL&P, $49.3 million for NSTAR Electric and $12.2 million for PSNH) of additional regulatory costs as of December 31, 2019 and 2018, respectively, that were included in long-term assets on the balance sheets.  These amounts represent incurred costs for which recovery has not yet been specifically approved by the applicable regulatory agency.  However, based on regulatory policies or past precedent on similar costs, management believes it is probable that these costs will ultimately be approved and recovered from customers in rates.  

Equity Return on Regulatory Assets:  For rate-making purposes, the regulated companies recover the carrying costs related to their regulatory assets.  For certain regulatory assets, the carrying cost recovered includes an equity return component.  This equity return, which is not recorded on the balance sheets, totaled $0.5 million and $0.7 million for CL&P as of December 31, 2019 and 2018, respectively, and $6.5 million and $12.0 million for PSNH as of December 31, 2019 and 2018, respectively. These carrying costs will be recovered from customers in future rates.  

Regulatory Liabilities:  The components of regulatory liabilities were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
EDIT due to Tax Cuts and Jobs Act	$	2,844.6	$	1,022.8	$	1,071.2	$	392.8	$	2,883.0	$	1,031.0	$	1,103.7	$	396.4
Cost of Removal	559.8		64.6		330.6		16.3		521.0		39.9		307.1		22.1
Benefit Costs	84.5		—		72.2		—		91.2		—		76.9		—
Regulatory Tracker Mechanisms	325.1		94.8		165.6		57.0		309.0		89.5		163.7		48.3
AFUDC - Transmission	73.2		46.0		27.2		—		70.7		47.4		23.3		—
Revenue Subject to Refund due to Tax Cuts   and Jobs Act	14.6		—		—		6.0		24.6		—		—		12.6
Other Regulatory Liabilities	117.4		19.6		59.0		7.1		80.2		24.0		29.2		4.2
Total Regulatory Liabilities	4,019.2		1,247.8		1,725.8		479.2		3,979.7		1,231.8		1,703.9		483.6
Less:  Current Portion	361.2		82.8		209.2		65.8		370.2		109.6		190.6		55.5
Total Long-Term Regulatory Liabilities	$	3,658.0	$	1,165.0	$	1,516.6	$	413.4	$	3,609.5	$	1,122.2	$	1,513.3	$	428.1

EDIT due to Tax Cuts and Jobs Act: Pursuant to the "Tax Cuts and Jobs Act" (the Act), which became law on December 22, 2017, Eversource had remeasured its existing deferred federal income tax balances to reflect the decrease in the U.S. federal corporate income tax rate from 35 percent to 21 percent. The remeasurement resulted in provisional regulated excess accumulated deferred income tax (excess ADIT or EDIT) liabilities that will benefit our customers in future periods and were recognized as regulatory liabilities on the balance sheet. EDIT liabilities related to property, plant, and equipment are subject to IRS normalization rules and will be returned to customers using the same timing as the remaining useful lives of the underlying assets that gave rise to the ADIT liabilities.

Eversource's regulated companies are in the process of, or will be, refunding the EDIT liabilities to customers based on orders issued by applicable state regulatory commissions. For CL&P (effective May 1, 2019) and Yankee Gas (effective November 15, 2018), the refund of EDIT liabilities was incorporated into base distribution rates. For NSTAR Electric (effective January 1, 2019) and NSTAR Gas (effective February 1, 2019), the refund of EDIT liabilities occurred in rates through a new reconciling factor. For PSNH, EDIT refunds will be addressed as part of the permanent distribution rate case filing. The EDIT balance related to PSNH's divested generation assets was included as a component of the securitization of the stranded generation assets and began to be refunded to customers, effective August 1, 2018. For our transmission companies, on November 21, 2019, the FERC issued its final rule requiring public utilities with transmission formula rates to make adjustments to ADIT and EDIT. Eversource expects to submit a filing demonstrating its compliance with the final rule in the second half of 2020.

Cost of Removal:  Eversource's regulated companies currently recover amounts in rates for future costs of removal of plant assets over the lives of the assets.  The estimated cost to remove utility assets from service is recognized as a component of depreciation expense, and the cumulative amount collected from customers but not yet expended is recognized as a regulatory liability.  

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AFUDC - Transmission:  Regulatory liabilities were recorded by CL&P and NSTAR Electric for AFUDC accrued on certain reliability-related transmission projects to reflect local rate base recovery.  These regulatory liabilities will be amortized over the depreciable life of the related transmission assets.

Revenue Subject to Refund due to Tax Cuts and Jobs Act: Eversource established a regulatory liability with a corresponding reduction to revenue, to reflect the difference between the 35 percent federal corporate income tax rate included in rates charged to customers and the 21 percent federal corporate income tax rate, effective January 1, 2018 as a result of the Tax Cuts and Jobs Act, until rates billed to customers reflected the lower federal tax rate. Effective May 1, 2018, CL&P adjusted distribution rates billed to customers to reflect the lower federal income tax rate prospectively and, as of December 31, 2018, fully refunded its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through April 30, 2018. Effective November 15, 2018, Yankee Gas adjusted distribution rates to reflect the lower federal income tax rate prospectively and to refund its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through November 14, 2018. Effective July 1, 2019, PSNH adjusted temporary distribution rates to reflect the lower federal income tax rate prospectively and to refund its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through June 30, 2019. For NSTAR Electric and NSTAR Gas, a December 2018 DPU order indicated that the DPU would not require a revision to base distribution rates for any potential refunds associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 to the effective dates of each company's rate changes (effective February 1, 2018 for NSTAR Electric and July 1, 2018 for NSTAR Gas).

Effective January 1, 2018, local transmission service rates were updated to reflect the lower U.S. federal corporate income tax rate that resulted from the act. On June 28, 2018, FERC granted a one-time tariff waiver of tariff provisions related to the federal corporate income tax rate so that effective June 1, 2018, the regional transmission service rates also reflected the reduced federal corporate income tax rate at 21 percent.

FERC ROE Complaints:  As of December 31, 2019, Eversource has a reserve established for the second ROE complaint in the pending FERC ROE complaint proceedings, which was recorded as a regulatory liability and is reflected within Regulatory Tracker Mechanisms in the table above.  The cumulative pre-tax reserve (excluding interest) as of December 31, 2019 totaled $39.1 million for Eversource (including $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH). See Note 13E, "Commitments and Contingencies – FERC ROE Complaints," for further information on developments in the pending ROE complaint proceedings.

3.     PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

Utility property, plant and equipment is recorded at original cost.  Original cost includes materials, labor, construction overheads and AFUDC for regulated property.  The cost of repairs and maintenance is charged to Operations and Maintenance expense as incurred.  

The following tables summarize property, plant and equipment by asset category:

Eversource	As of December 31,
(Millions of Dollars)	2019			2018
Distribution - Electric	$	15,880.0		$	15,071.1
Distribution - Natural Gas	3,931.1			3,546.2
Transmission - Electric	10,958.4			10,153.9
Distribution - Water	1,726.5			1,639.8
Solar	200.2			164.1
Utility	32,696.2			30,575.1
Other (1)	1,025.6			778.6
Property, Plant and Equipment, Gross	33,721.8			31,353.7
Less:  Accumulated Depreciation
Utility	(7,483.5		)	(7,126.2		)
Other	(387.4		)	(336.7		)
Total Accumulated Depreciation	(7,870.9		)	(7,462.9		)
Property, Plant and Equipment, Net	25,850.9			23,890.8
Construction Work in Progress	1,734.6			1,719.6
Total Property, Plant and Equipment, Net	$	27,585.5		$	25,610.4

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	As of December 31,
	2019									2018
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Distribution - Electric	$	6,485.5		$	7,163.7		$	2,271.1		$	6,176.4		$	6,756.4		$	2,178.6
Transmission - Electric	5,043.0			4,411.9			1,498.7			4,700.5			4,065.9			1,338.7
Solar	—			200.2			—			—			164.1			—
Property, Plant and Equipment, Gross	11,528.5			11,775.8			3,769.8			10,876.9			10,986.4			3,517.3
Less:  Accumulated Depreciation	(2,385.7		)	(2,895.3		)	(799.9		)	(2,302.6		)	(2,702.0		)	(772.9		)
Property, Plant and Equipment, Net	9,142.8			8,880.5			2,969.9			8,574.3			8,284.4			2,744.4
Construction Work in Progress	483.0			592.3			159.6			335.4			510.3			135.7
Total Property, Plant and Equipment, Net	$	9,625.8		$	9,472.8		$	3,129.5		$	8,909.7		$	8,794.7		$	2,880.1

⁽¹⁾  These assets are primarily comprised of computer software, hardware and equipment at Eversource Service and buildings at The Rocky River Realty Company.

In 2019, Eversource recorded an impairment charge for the NPT project costs, which had been recorded within both Construction Work in Progress and the Transmission - Electric asset categories. For further information regarding the impairment of NPT, see Note 1D, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements.

Depreciation of utility assets is calculated on a straight-line basis using composite rates based on the estimated remaining useful lives of the various classes of property (estimated useful life for PSNH distribution and the water utilities).  The composite rates, which are subject to approval by the appropriate state regulatory agency, include a cost of removal component, which is collected from customers over the lives of the plant assets and is recognized as a regulatory liability.  Depreciation rates are applied to property from the time it is placed in service.

Upon retirement from service, the cost of the utility asset is charged to the accumulated provision for depreciation.  The actual incurred removal costs are applied against the related regulatory liability.  

The depreciation rates for the various classes of utility property, plant and equipment aggregate to composite rates as follows:

(Percent)	2019		2018		2017
Eversource	3.0	%	2.9	%	3.0	%
CL&P	2.8	%	2.8	%	2.8	%
NSTAR Electric	2.8	%	2.8	%	2.9	%
PSNH	2.8	%	2.8	%	3.1	%

The following table summarizes average remaining useful lives of depreciable assets:

	As of December 31, 2019
(Years)	Eversource	CL&P	NSTAR Electric	PSNH
Distribution - Electric	34.3	35.3	33.7	33.2
Distribution - Natural Gas	43.2	—	—	—
Transmission - Electric	40.4	36.8	44.9	42.1
Distribution - Water	33.5	—	—	—
Solar	24.2	—	24.2	—
Other (1)	11.2	—	—	—

⁽¹⁾  The estimated useful life of computer software, hardware and equipment primarily ranges from 5 to 15 years and of buildings is 40 years.

4.     DERIVATIVE INSTRUMENTS

The electric and natural gas companies purchase and procure energy and energy-related products, which are subject to price volatility, for their customers.  The costs associated with supplying energy to customers are recoverable from customers in future rates.  These regulated companies manage the risks associated with the price volatility of energy and energy-related products through the use of derivative and non-derivative contracts.  

Many of the derivative contracts meet the definition of, and are designated as, normal and qualify for accrual accounting under the applicable accounting guidance.  The costs and benefits of derivative contracts that meet the definition of normal are recognized in Operating Expenses on the statements of income, as applicable, as electricity or natural gas is delivered.

Derivative contracts that are not designated as normal are recorded at fair value as current or long-term Derivative Assets or Derivative Liabilities on the balance sheets.  For the electric and natural gas companies, regulatory assets or regulatory liabilities are recorded to offset the fair values of derivatives, as contract settlement amounts are recovered from, or refunded to, customers in their respective energy supply rates.  

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The gross fair values of derivative assets and liabilities with the same counterparty are offset and reported as net Derivative Assets or Derivative Liabilities, with current and long-term portions, on the balance sheets.  The following table presents the gross fair values of contracts, categorized by risk type, and the net amounts recorded as current or long-term derivative assets or liabilities:

		As of December 31,
		2019									2018
(Millions of Dollars)	Fair Value Hierarchy	Commodity Supply and Price Risk Management			Netting (1)			Net Amount Recorded as a Derivative			Commodity Supply and Price Risk Management			Netting (1)			Net Amount Recorded as a Derivative
Current Derivative Assets:
CL&P	Level 3	$	12.2		$	(0.4	)	$	11.8		$	9.6		$	(3.4	)	$	6.2
Other	Level 2	—			—			—			1.5			(0.9		)	0.6
Long-Term Derivative Assets:
CL&P	Level 3	67.5			(2.1		)	65.4			74.2			(2.3		)	71.9
Current Derivative Liabilities:
CL&P	Level 3	(67.8		)	—			(67.8		)	(55.1		)	—			(55.1		)
Other	Level 2	(5.2		)	—			(5.2		)	—			—			—
Long-Term Derivative Liabilities:
CL&P	Level 3	(338.6		)	—			(338.6		)	(379.5		)	—			(379.5		)
Other	Level 2	(0.1		)	—			(0.1		)	—			—			—

⁽¹⁾ Amounts represent derivative assets and liabilities that Eversource elected to record net on the balance sheets.  These amounts are subject to master netting agreements or similar agreements for which the right of offset exists.

The business activities that result in the recognition of derivative assets also create exposure to various counterparties.  As of December 31, 2019, CL&P's derivative assets were exposed to counterparty credit risk and contracted with investment grade entities.  

For further information on the fair value of derivative contracts, see Note 1I, "Summary of Significant Accounting Policies – Fair Value Measurements," and Note 1J, "Summary of Significant Accounting Policies – Derivative Accounting," to the financial statements.

Derivative Contracts at Fair Value with Offsetting Regulatory Amounts

Commodity Supply and Price Risk Management:  As required by regulation, CL&P, along with UI, has capacity-related contracts with generation facilities.  CL&P has a sharing agreement with UI, with 80 percent of the costs or benefits of each contract borne by or allocated to CL&P and 20 percent borne by or allocated to UI.  The combined capacities of these contracts as of December 31, 2019 and 2018 were 676 MW and 787 MW, respectively.  The capacity contracts extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market price received in the ISO-NE capacity markets.  In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020.

As of December 31, 2019 and 2018, Eversource had New York Mercantile Exchange (NYMEX) financial contracts for natural gas futures in order to reduce variability associated with the price of 9.6 million and 12.5 million MMBtu of natural gas, respectively.

For the years ended December 31, 2019, 2018 and 2017, there were losses of $20.7 million, $25.0 million and $29.0 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource's derivative contracts.

Fair Value Measurements of Derivative Instruments

Derivative contracts classified as Level 2 in the fair value hierarchy relate to the financial contracts for natural gas futures.  Prices are obtained from broker quotes and are based on actual market activity.  The contracts are valued using NYMEX natural gas prices.  Valuations of these contracts also incorporate discount rates using the yield curve approach.  

The fair value of derivative contracts classified as Level 3 utilizes significant unobservable inputs.  The fair value is modeled using income techniques, such as discounted cash flow valuations adjusted for assumptions related to exit price.  Significant observable inputs for valuations of these contracts include energy and energy-related product prices in future years for which quoted prices in an active market exist.  Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy and energy-related products, and accounting requirements.  The future capacity prices for periods that are not quoted in an active market or established at auction are based on available market data and are escalated based on estimates of inflation in order to address the full term of the contract.  

Valuations of derivative contracts using a discounted cash flow methodology include assumptions regarding the timing and likelihood of scheduled payments and also reflect non-performance risk, including credit, using the default probability approach based on the counterparty's credit rating for assets and the Company's credit rating for liabilities.  Valuations incorporate estimates of premiums or discounts that would be required by a market participant to arrive at an exit price, using historical market transactions adjusted for the terms of the contract.  

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The following is a summary of Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts:

	As of December 31,
	2019						2018
CL&P	Range					Period Covered	Range					Period Covered
Capacity Prices	$	3.01	—	7.34	per kW-Month	2023 - 2026	$	4.30	—	7.44	per kW-Month	2022 - 2026
Forward Reserve	0.80		—	1.90	per kW-Month	2020 - 2024	0.75		—	1.78	per kW-Month	2019 - 2024

Exit price premiums of 2.1 percent through 13.6 percent are also applied to these contracts and reflect the uncertainty and illiquidity premiums that would be required based on the most recent market activity available for similar type contracts.

Significant increases or decreases in future capacity or forward reserve prices in isolation would decrease or increase, respectively, the fair value of the derivative liability.  Any increases in risk premiums would increase the fair value of the derivative liability.  Changes in these fair values are recorded as a regulatory asset or liability and do not impact net income.  

Valuations using significant unobservable inputs:  The following table presents changes in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis.  The derivative assets and liabilities are presented on a net basis.

CL&P (Millions of Dollars)	For the Years Ended December 31,
	2019			2018
Derivatives, Net:
Fair Value as of Beginning of Period	$	(356.5	)	$	(362.3	)
Net Realized/Unrealized Losses Included in Regulatory Assets	(15.0		)	(32.0		)
Settlements	42.3			37.8
Fair Value as of End of Period	$	(329.2	)	$	(356.5	)

5.     MARKETABLE SECURITIES

Eversource holds marketable securities that are primarily used to fund certain non-qualified executive benefits.  The trusts that hold marketable securities are not subject to regulatory oversight by state or federal agencies.  CYAPC and YAEC maintain legally restricted trusts, each of which holds marketable securities, to fund the spent nuclear fuel removal obligations of their nuclear fuel storage facilities.

Equity Securities: Unrealized gains and losses on equity securities held in Eversource's non-qualified executive benefit trust are recorded in Other Income, Net on the statements of income. The fair value of these equity securities as of December 31, 2019 and 2018 was $45.7 million and $44.0 million, respectively.  For the years ended December 31, 2019 and 2018, there were unrealized gains of $9.8 million and unrealized losses of $4.3 million recorded in Other Income, Net related to these equity securities, respectively.

Eversource's equity securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of $182.8 million and $200.0 million as of December 31, 2019 and 2018, respectively.  Unrealized gains and losses for these spent nuclear fuel trusts are subject to regulatory accounting treatment and are recorded in Marketable Securities with the corresponding offset to Other Long-Term Liabilities on the balance sheets, with no impact on the statements of income.

Available-for-Sale Debt Securities:  The following is a summary of the available-for-sale debt securities, which are recorded at fair value and are included in current and long-term Marketable Securities on the balance sheets.

	As of December 31,
	2019									2018
Eversource (Millions of Dollars)	Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value
Debt Securities	$	228.4	$	5.8	$	(0.1	)	$	234.1	$	190.0	$	0.4	$	(4.0	)	$	186.4

Eversource's debt securities include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts in the amounts of $198.1 million and $143.9 million as of December 31, 2019 and 2018, respectively.  

Unrealized gains and losses on available-for-sale debt securities held in Eversource's non-qualified benefit trust are recorded in Accumulated Other Comprehensive Income. There have been no significant unrealized losses, other-than-temporary impairments, or credit losses for the years ended December 31, 2019 or 2018.  Factors considered in determining whether a credit loss exists include the duration and severity of the impairment, adverse conditions specifically affecting the issuer, and the payment history, ratings and rating changes of the security.  For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated.

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As of December 31, 2019, the contractual maturities of available-for-sale debt securities were as follows:    

Eversource (Millions of Dollars)	Amortized Cost		Fair Value
Less than one year (1)	$	59.2	$	59.3
One to five years	40.5		41.4
Six to ten years	33.6		34.8
Greater than ten years	95.1		98.6
Total Debt Securities	$	228.4	$	234.1

⁽¹⁾ Amounts in the Less than one year category include securities in the CYAPC and YAEC spent nuclear fuel trusts, which are restricted and are classified in long-term Marketable Securities on the balance sheets.

Realized Gains and Losses:  Realized gains and losses are recorded in Other Income, Net for Eversource's benefit trust and are offset in Other Long-Term Liabilities for CYAPC and YAEC.  Eversource utilizes the specific identification basis method for the Eversource non-qualified benefit trust, and the average cost basis method for the CYAPC and YAEC spent nuclear fuel trusts to compute the realized gains and losses on the sale of marketable securities.

Fair Value Measurements:  The following table presents the marketable securities recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:

Eversource (Millions of Dollars)	As of December 31,
	2019		2018
Level 1:
Mutual Funds and Equities	$	228.5	$	244.0
Money Market Funds	46.0		25.9
Total Level 1	$	274.5	$	269.9
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury)	$	96.8	$	79.6
Corporate Debt Securities	44.0		39.5
Asset-Backed Debt Securities	12.9		14.0
Municipal Bonds	26.7		19.2
Other Fixed Income Securities	7.7		8.2
Total Level 2	$	188.1	$	160.5
Total Marketable Securities	$	462.6	$	430.4

U.S. government issued debt securities are valued using market approaches that incorporate transactions for the same or similar bonds and adjustments for yields and maturity dates.  Corporate debt securities are valued using a market approach, utilizing recent trades of the same or similar instruments and also incorporating yield curves, credit spreads and specific bond terms and conditions.  Asset-backed debt securities include collateralized mortgage obligations, commercial mortgage backed securities, and securities collateralized by auto loans, credit card loans or receivables.  Asset-backed debt securities are valued using recent trades of similar instruments, prepayment assumptions, yield curves, issuance and maturity dates, and tranche information.  Municipal bonds are valued using a market approach that incorporates reported trades and benchmark yields.  Other fixed income securities are valued using pricing models, quoted prices of securities with similar characteristics, and discounted cash flows.

6.     INVESTMENTS IN UNCONSOLIDATED AFFILIATES

Investments in entities that are not consolidated are included in long-term assets on the balance sheets and earnings impacts from these equity investments are included in Other Income, Net on the statements of income.  Eversource's investments included the following:

			Investment Balance as of December 31,
(Millions of Dollars)	Ownership Interest		2019		2018
Offshore Wind Business - North East Offshore and Bay State Wind	50	%	$	649.3	$	234.3
Natural Gas Pipeline - Algonquin Gas Transmission, LLC	15	%	127.8		155.0
Renewable Energy Investment Fund	90	%	72.4		54.1
Other	various		22.1		20.9
Total Investments in Unconsolidated Affiliates			$	871.6	$	464.3

For the years ended December 31, 2019, 2018 and 2017, Eversource had equity in earnings, net of impairment, of unconsolidated affiliates of $42.2 million, $3.8 million, and $27.4 million, respectively. Eversource received dividends from its equity method investees of $48.9 million, $22.3 million and $20.0 million, respectively, for the years ended December 31, 2019, 2018 and 2017.

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Investments in affiliates where Eversource has the ability to exercise significant influence, but not control, over an investee are initially recognized as an equity method investment at cost. Any differences between the cost of an investment and the amount of underlying equity in net assets of an investee are considered basis differences, and are determined based upon the estimated fair values of the investee's identifiable assets and liabilities. The carrying amount of Eversource’s offshore wind investments exceeded its share of underlying equity in net assets by $240.3 million and $7.2 million, respectively, as of December 31, 2019 and 2018. As of December 31, 2019, these basis differences are primarily comprised of $168.3 million of equity method goodwill that is not being amortized, intangible assets for PPAs, which will be amortized over the term of the PPAs, and capitalized interest.

Offshore Wind Business: Eversource's offshore wind business includes ownership interests in North East Offshore and Bay State Wind, which together hold PPAs and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind projects, as well as offshore leases through BOEM. Eversource's offshore wind projects are being developed and constructed through a joint and equal partnership with Ørsted. On February 8, 2019, Eversource and Ørsted entered into an equal partnership to acquire key offshore wind assets in the Northeast. Eversource has a 50 percent ownership interest in North East Offshore, which holds the Revolution Wind and South Fork Wind projects, as well as a 257 square-mile lease off the coasts of Massachusetts and Rhode Island. Eversource also has a 50 percent ownership interest in Bay State Wind, which holds the Sunrise Wind project. Bay State Wind's separate 300-square-mile ocean lease is located approximately 25 miles south of the coast of Massachusetts adjacent to the North East Offshore area.

NSTAR Electric: As of December 31, 2019 and 2018, NSTAR Electric's investments included a 14.5 percent ownership interest in two companies that transmit hydro-electricity imported from the Hydro-Quebec system in Canada of $8.2 million and $7.6 million, respectively.

Impairment of Equity Method Investments: Equity method investments are assessed for impairment when conditions exist that indicate that the fair value of the investment is less than book value.  If the decline in value is considered to be other-than-temporary, the investment is written down to its estimated fair value, which establishes a new cost basis in the investment. Impairment evaluations involve a significant degree of judgment and estimation, including identifying circumstances that indicate an impairment may exist and developing undiscounted future cash flows.

During the year ended December 31, 2018, Eversource recorded an other-than-temporary impairment of $32.9 million within Other Income, Net on our statement of income, related to Access Northeast, a natural gas pipeline and storage project, which represented the full carrying value of our equity method investment. On April 1, 2019, pursuant to a provision in the partnership agreement jointly entered into by Eversource, Enbridge, Inc. and National Grid plc, through Algonquin Gas Transmission, LLC, the Access Northeast project was terminated.

7.     ASSET RETIREMENT OBLIGATIONS

Eversource, including CL&P, NSTAR Electric and PSNH, recognizes a liability for the fair value of an ARO on the obligation date if the liability's fair value can be reasonably estimated, even if it is conditional on a future event.  Settlement dates and future costs are reasonably estimated when sufficient information becomes available.  Management has identified various categories of AROs, primarily CYAPC's and YAEC's obligation to dispose of spent nuclear fuel and high level waste, and also certain assets containing asbestos and hazardous contamination. Management has performed fair value calculations reflecting expected probabilities for settlement scenarios.

The fair value of an ARO is recorded as a liability in Other Long-Term Liabilities with a corresponding amount included in Property, Plant and Equipment, Net on the balance sheets.  The ARO assets are depreciated, and the ARO liabilities are accreted over the estimated life of the obligation and the corresponding credits are recorded as accumulated depreciation and ARO liabilities, respectively.  As the electric and natural gas companies are rate-regulated on a cost-of-service basis, these companies apply regulatory accounting guidance and both the depreciation and accretion costs associated with these companies' AROs are recorded as increases to Regulatory Assets on the balance sheets.  

A reconciliation of the beginning and ending carrying amounts of ARO liabilities is as follows:

	As of December 31,
	2019											2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH		Eversource			CL&P		NSTAR Electric		PSNH
Balance as of Beginning of Year	$	466.2		$	33.5		$	72.4		$	4.0	$	419.1		$	31.5	$	44.6	$	25.0
Liabilities Incurred During the Year	30.3			—			30.3			—		11.3			—		11.3		—
Liabilities Settled During the Year	(21.3		)	(3.6		)	—			—		(36.6		)	—		—		(21.5		)
Accretion	27.1			2.2			3.5			0.2		25.5			2.0		2.2		0.5
Revisions in Estimated Cash Flows	(12.8		)	(0.1		)	(8.7		)	—		46.9			—		14.3		—
Balance as of End of Year	$	489.5		$	32.0		$	97.5		$	4.2	$	466.2		$	33.5	$	72.4	$	4.0

The ARO balance includes the current portion of $1.0 million for Eversource and NSTAR Electric as of December 31, 2019, which is included in Other Current Liabilities on the balance sheets.

Eversource's amounts include CYAPC and YAEC's AROs of $337.7 million and $339.9 million as of December 31, 2019 and 2018, respectively. The fair value of the ARO for CYAPC and YAEC includes uncertainties of the fuel off-load dates related to the DOE's timing of performance regarding its obligation to dispose of the spent nuclear fuel and high level waste and other assumptions, including discount rates.  The incremental asset recorded as an offset to the ARO liability was fully depreciated since the plants have no remaining useful life.  Any changes in the ARO liability are recorded with a corresponding offset to the related regulatory asset.  The assets held in the CYAPC and YAEC spent nuclear fuel trusts

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are restricted for settling the ARO and all other nuclear fuel storage obligations.  For further information on the assets held in the spent nuclear fuel trusts, see Note 5, "Marketable Securities," to the financial statements.

The increase in the ARO balance at NSTAR Electric for the year ended December 31, 2019 was due to the recording of a new liability associated with the installation of a 115kV distribution cable across Boston Harbor to Deer Island that was placed into service in 2019. See Note 13F, "Commitments and Contingencies - Eversource and NSTAR Electric Boston Harbor Civil Action," to the financial statements for further information on the HEEC distribution cable.

8.     SHORT-TERM DEBT

Short-Term Debt Borrowing Limits:  The amount of short-term borrowings that may be incurred by CL&P and NSTAR Electric is subject to periodic approval by the FERC.  Because the NHPUC has jurisdiction over PSNH's short-term debt, PSNH is not currently required to obtain FERC approval for its short-term borrowings.  On October 25, 2019, the FERC granted authorization that allows CL&P to issue total short-term borrowings in an aggregate principal amount not to exceed $600 million outstanding at any one time, through December 31, 2021.  On December 18, 2019, the FERC granted authorization that allows NSTAR Electric to issue total short-term borrowings in an aggregate principal amount not to exceed $655 million outstanding at any one time, through December 31, 2021.

PSNH is authorized by regulation of the NHPUC to incur short-term borrowings up to 10 percent of net fixed plant plus an additional $60 million until further ordered by the NHPUC.  As of December 31, 2019, PSNH's short-term debt authorization under the 10 percent of net fixed plant test plus $60 million totaled approximately $354 million.  

CL&P's certificate of incorporation contains preferred stock provisions restricting the amount of unsecured debt that CL&P may incur, including limiting unsecured indebtedness with a maturity of less than 10 years to 10 percent of total capitalization.  As of December 31, 2019, CL&P had $738.1 million of unsecured debt capacity available under this authorization.

Yankee Gas and NSTAR Gas are not required to obtain approval from any state or federal authority to incur short-term debt.

Commercial Paper Programs and Credit Agreements: Eversource parent has a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas and Aquarion Water Company of Connecticut are also parties to a five-year $1.45 billion revolving credit facility. Effective December 9, 2019, the revolving credit facility's termination date was extended for one additional year to December 6, 2024. The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program.

NSTAR Electric has a $650 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. NSTAR Electric is also a party to a five-year $650 million revolving credit facility. Effective December 9, 2019, the revolving credit facility's termination date was extended for one additional year to December 6, 2024. The revolving credit facility serves to backstop NSTAR Electric's $650 million commercial paper program.

The amount of borrowings outstanding and available under the commercial paper programs were as follows:

	Borrowings Outstanding  as of December 31,				Available Borrowing Capacity as of December 31,				Weighted-Average Interest Rate as of December 31,
(Millions of Dollars)	2019		2018		2019		2018		2019		2018
Eversource Parent Commercial Paper Program	$	1,224.9	$	631.5	$	225.1	$	818.5	1.98	%	2.77	%
NSTAR Electric Commercial Paper Program	10.5		278.5		639.5		371.5		1.63	%	2.50	%

There were no borrowings outstanding on either the Eversource parent or NSTAR Electric revolving credit facilities as of December 31, 2019 or 2018.

Amounts outstanding under the commercial paper programs and revolving credit facilities are included in Notes Payable and classified in current liabilities on the Eversource and NSTAR Electric balance sheets as all borrowings are outstanding for no more than 364 days at one time.  As a result of the Eversource parent long-term debt issuance on January 10, 2020, the net proceeds of which were used to repay short-term borrowings outstanding under its commercial paper program, $346.3 million of commercial paper borrowings under the Eversource parent commercial paper program were classified as Long-Term Debt as of December 31, 2019.

Under the credit facilities described above, Eversource and its subsidiaries must comply with certain financial and non-financial covenants, including a consolidated debt to total capitalization ratio.  As of December 31, 2019 and 2018, Eversource and its subsidiaries were in compliance with these covenants. If Eversource or its subsidiaries were not in compliance with these covenants, an event of default would occur requiring all outstanding borrowings by such borrower to be repaid, and additional borrowings by such borrower would not be permitted under its respective credit facility.

The Company expects the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.

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Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of December 31, 2019, there were intercompany loans from Eversource parent to CL&P of $63.8 million, to PSNH of $27.0 million, and to a subsidiary of NSTAR Electric of $30.3 million. As of December 31, 2018, there were intercompany loans from Eversource parent to PSNH of $57.0 million. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets.

9.    LONG-TERM DEBT

Details of long-term debt outstanding are as follows:

CL&P (Millions of Dollars)	As of December 31,
	2019			2018
First Mortgage Bonds:
7.875% 1994 Series D due 2024	$	139.8		$	139.8
5.750% 2004 Series B due 2034	130.0			130.0
5.625% 2005 Series B due 2035	100.0			100.0
6.350% 2006 Series A due 2036	250.0			250.0
5.750% 2007 Series B due 2037	150.0			150.0
6.375% 2007 Series D due 2037	100.0			100.0
5.500% 2009 Series A due 2019	—			250.0
2.500% 2013 Series A due 2023	400.0			400.0
4.300% 2014 Series A due 2044	475.0			475.0
4.150% 2015 Series A due 2045	350.0			350.0
3.200% 2017 Series A due 2027	500.0			300.0
4.000% 2018 Series A due 2048	800.0			500.0
Total First Mortgage Bonds	3,394.8			3,144.8
Pollution Control Revenue Bonds:
4.375% Fixed Rate Tax Exempt due 2028	120.5			120.5
Less Amounts due Within One Year	—			(250.0		)
Unamortized Premiums and Discounts, Net	27.8			10.2
Unamortized Debt Issuance Costs	(25.0		)	(21.5		)
CL&P Long-Term Debt	$	3,518.1		$	3,004.0

NSTAR Electric (Millions of Dollars)	As of December 31,
	2019			2018
Debentures:
5.750% due 2036	$	200.0		$	200.0
5.500% due 2040	300.0			300.0
2.375% due 2022	400.0			400.0
4.400% due 2044	300.0			300.0
3.250% due 2025	250.0			250.0
2.700% due 2026	250.0			250.0
3.200% due 2027	700.0			700.0
3.250% due 2029	400.0			—
Total Debentures	2,800.0			2,400.0
Notes:
5.900% Senior Notes Series B due 2034	50.0			50.0
6.700% Senior Notes Series D due 2037	40.0			40.0
5.100% Senior Notes Series E due 2020	95.0			95.0
3.500% Senior Notes Series F due 2021	250.0			250.0
3.880% Senior Notes Series G due 2023	80.0			80.0
2.750% Senior Notes Series H due 2026	50.0			50.0
Total Notes	565.0			565.0
Less Amounts due Within One Year	(95.0		)	—
Unamortized Premiums and Discounts, Net	(4.1		)	(2.5		)
Unamortized Debt Issuance Costs	(18.8		)	(17.7		)
NSTAR Electric Long-Term Debt	$	3,247.1		$	2,944.8

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PSNH (Millions of Dollars)	As of December 31,
	2019			2018
First Mortgage Bonds:
5.600% Series M due 2035	$	50.0		$	50.0
4.500% Series P due 2019	—			150.0
4.050% Series Q due 2021	122.0			122.0
3.200% Series R due 2021	160.0			160.0
3.500% Series S due 2023	325.0			325.0
3.600% Series T due 2049	300.0			—
Total First Mortgage Bonds	957.0			807.0
Less Amounts due Within One Year	—			(150.0		)
Unamortized Premiums and Discounts, Net	(0.7		)	—
Unamortized Debt Issuance Costs	(4.7		)	(1.8		)
PSNH Long-Term Debt	$	951.6		$	655.2

OTHER (Millions of Dollars)	As of December 31,
	2019			2018
Yankee Gas - First Mortgage Bonds: 2.230% - 8.480% due 2020 - 2049	$	620.0		$	470.0
NSTAR Gas - First Mortgage Bonds: 3.740% - 9.950% due 2020 - 2049	460.0			385.0
Aquarion - Senior Note 4.000% due 2024	360.0			360.0
Aquarion - Unsecured Notes 0% - 6.430% due 2021 - 2049	335.3			289.5
Aquarion - Secured Debt 4.100% - 9.640% due 2021 - 2035	68.8			70.7
Eversource Parent - Debentures 4.500% due 2019	—			350.0
Eversource Parent - Senior Notes 2.500% - 4.250% due 2021 - 2029	4,000.0			4,000.0
Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)	11.6			39.5
Fair Value Adjustment (1)	109.1			144.7
Less Fair Value Adjustment - Current Portion (1)	(31.3		)	(36.2		)
Less Amounts due in One Year	(201.1		)	(401.1		)
Commercial Paper Classified as Long-Term Debt (See Note 8, Short-Term Debt)	346.3			—
Unamortized Premiums and Discounts, Net	(4.1		)	(4.2		)
Unamortized Debt Issuance Costs	(20.6		)	(23.2		)
Total Other Long-Term Debt	$	6,054.0		$	5,644.7
Total Eversource Long-Term Debt	$	13,770.8		$	12,248.7

⁽¹⁾ The fair value adjustment amount is the purchase price adjustments, net of amortization, required to record long-term debt at fair value on the dates of the 2012 merger with NSTAR and the 2017 acquisition of Aquarion.

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Long-Term Debt Issuances and Repayments: The following table summarizes long-term debt issuances and repayments:

(Millions of Dollars)	Issue Date	Issuance/(Repayment)			Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P:
4.00% 2018 Series A First Mortgage Bonds (1)	April 2019	$	300.0		April 2048	Paid short-term borrowings that were used to pay long-term debt that matured on February 1, 2019 and fund capital expenditures and working capital
3.20% 2017 Series A First Mortgage Bonds (2)	September 2019	200.0			March 2027	Paid short-term borrowings and fund capital expenditures and working capital
5.50% 2009 Series A First Mortgage Bonds	February 2009	(250.0		)	February 2019	Paid at maturity on February 1, 2019
NSTAR Electric:
3.25% 2019 Debentures	May 2019	400.0			May 2029	Paid short-term borrowings that were used to fund investments in eligible green expenditures
PSNH:
3.60% 2019 Series T First Mortgage Bonds	June 2019	300.0			July 2049	Paid long-term debt that matured in December 2019, paid short-term borrowings and fund capital expenditures and working capital
4.50% 2009 Series P First Mortgage Bonds	December 2009	(150.0		)	December 2019	Paid at maturity on December 1, 2019
Other:
Eversource Parent 4.50% Debentures	November 2009	(350.0		)	November 2019	Paid at maturity on November 15, 2019
Eversource Parent 3.45% Series P Senior Notes	January 2020	350.0			January 2050	Paid short-term borrowings
NSTAR Gas 3.74% Series Q First Mortgage Bonds	July 2019	75.0			August 2049	Paid short-term borrowings and fund capital expenditures and working capital
Yankee Gas 2.23% Series P First Mortgage Bonds	September 2019	100.0			October 2024	Paid short-term borrowings and for general corporate purposes
Yankee Gas 3.30% Series Q First Mortgage Bonds	September 2019	100.0			October 2049	Paid short-term borrowings and for general corporate purposes
Yankee Gas 5.26% Series H First Mortgage Bonds	November 2004	(50.0		)	November 2019	Paid at maturity on November 1, 2019
Aquarion 3.54% Senior Notes	December 2019	45.0			December 2049	Paid short-term borrowings

⁽¹⁾ These bonds are part of the same series issued by CL&P in March 2018. The aggregate outstanding principal amount of these bonds is now $800 million.

⁽²⁾ These bonds are part of the same series issued by CL&P in March 2017. The aggregate outstanding principal amount of these bonds is now $500 million.

Long-Term Debt Issuance Authorizations: On February 27, 2019, the DPU approved NSTAR Electric's request for authorization to issue up to $800 million in long-term debt through December 31, 2020. On April 26, 2019, the NHPUC approved PSNH's request for authorization to issue up to $300 million in long-term debt through December 31, 2019. On August 14, 2019, PURA approved CL&P's request for authorization to issue up to $675 million in long-term debt through December 31, 2022. On December 11, 2019, PURA approved Aquarion Water Company of Connecticut's request for authorization to issue up to $45 million of long-term debt. On January 27, 2020, the DPU approved NSTAR Gas' request for authorization to issue up to $270 million in long-term debt through December 31, 2021.

Long-Term Debt Provisions:  The utility plant of CL&P, PSNH, Yankee Gas, NSTAR Gas and a portion of Aquarion is subject to the lien of each company's respective first mortgage bond indenture.  The Eversource parent, NSTAR Electric and a portion of Aquarion debt is unsecured.  Additionally, the long-term debt agreements provide that Eversource and certain of its subsidiaries must comply with certain covenants as are customarily included in such agreements, including equity requirements for NSTAR Electric, NSTAR Gas and Aquarion.  Under the equity requirements, NSTAR Electric's and Aquarion's senior notes must maintain a certain consolidated indebtedness to capitalization ratio as of the end of any fiscal quarter and NSTAR Gas' outstanding long-term debt must not exceed equity.

CL&P's obligation to repay the Pollution Control Revenue Bonds (PCRBs) is secured by first mortgage bonds.  The first mortgage bonds contain similar terms and provisions as the applicable series of PCRBs.  If CL&P fails to meet its obligations under the first mortgage bonds, then the holder of the first mortgage bonds (the issuer of the PCRBs) would have rights under the first mortgage bonds.  CL&P's tax-exempt PCRBs will be subject to redemption at par on or after September 1, 2021.  

Certain secured and unsecured long-term debt securities are callable at redemption price or are subject to make-whole provisions.

Eversource, NSTAR Electric, Yankee Gas and Aquarion have certain long-term debt agreements that contain cross-default provisions.  No other debt issuances contain cross-default provisions as of December 31, 2019.

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CYAPC's Pre-1983 Spent Nuclear Fuel Obligation:  Under the Nuclear Waste Policy Act of 1982, the DOE is responsible for the selection and development of repositories for, and the disposal of, spent nuclear fuel and high-level radioactive waste. CYAPC is obligated to pay the DOE for the costs to dispose of spent nuclear fuel and high-level radioactive waste generated prior to April 7, 1983 (pre-1983 Spent Nuclear Fuel) and recorded an accrual for the full liability thereof to the DOE. This liability accrues interest costs at the 3-month Treasury bill yield rate. For nuclear fuel used to generate electricity prior to April 7, 1983, payment may be made any time prior to the first delivery of spent fuel to the DOE. Fees for disposal of nuclear fuel burned on or after April 7, 1983 were billed to member companies and paid to the DOE.

As of December 31, 2019 and 2018, as a result of consolidating CYAPC, Eversource has consolidated $11.6 million and $39.5 million, respectively, in pre-1983 spent nuclear fuel obligations to the DOE. In December 2019 and 2018, CYAPC paid $29 million and $145 million, respectively, to the DOE to partially settle this obligation. The obligation includes accumulated interest costs of $8.6 million and $29.0 million as of December 31, 2019 and 2018, respectively.  CYAPC maintains a trust to fund amounts due to the DOE for the disposal of pre-1983 spent nuclear fuel.  For further information, see Note 5, "Marketable Securities," to the financial statements.

Long-Term Debt Maturities:  Long-term debt maturities on debt outstanding for the years 2020 through 2024 and thereafter are shown below. These amounts exclude PSNH rate reduction bonds, CYAPC pre-1983 spent nuclear fuel obligation, net unamortized premiums, discounts and debt issuance costs, and other fair value adjustments as of December 31, 2019:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2020	$	296.1	$	—	$	95.0	$	—
2021	1,033.6		—		250.0		282.0
2022	1,188.9		—		400.0		—
2023	1,665.2		400.0		80.0		325.0
2024	1,049.8		139.8		—		—
Thereafter	8,447.8		2,975.5		2,540.0		350.0
Total	$	13,681.4	$	3,515.3	$	3,365.0	$	957.0

10.    RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

Rate Reduction Bonds: On May 8, 2018, PSNH Funding, a wholly-owned subsidiary of PSNH, issued $635.7 million of securitized RRBs in multiple tranches with a weighted average interest rate of 3.66 percent, and final maturity dates ranging from 2026 to 2035.  The RRBs are expected to be repaid by February 1, 2033. RRB payments consist of principal and interest and are paid semi-annually, beginning on February 1, 2019. The RRBs were issued pursuant to a finance order issued by the NHPUC on January 30, 2018 to recover remaining costs resulting from the divestiture of PSNH’s generation assets.

The proceeds were used by PSNH Funding to purchase PSNH’s stranded cost asset-recovery property, including its vested property right to bill, collect and adjust a non-bypassable stranded cost recovery charge from PSNH’s retail customers. The collections are used to pay principal, interest and other costs in connection with the RRBs. The RRBs are secured by the stranded cost asset-recovery property. Cash collections from the stranded cost recovery charges and funds on deposit in trust accounts are the sole source of funds to satisfy the debt obligation. PSNH is not the owner of the RRBs, and PSNH Funding’s assets and revenues are not available to pay PSNH’s creditors. The RRBs are non-recourse senior secured obligations of PSNH Funding and are not insured or guaranteed by PSNH or Eversource Energy.

PSNH Funding was formed solely to issue RRBs to finance PSNH’s unrecovered remaining costs associated with the divestiture of its generation assets. PSNH Funding is considered a VIE primarily because the equity capitalization is insufficient to support its operations. PSNH has the power to direct the significant activities of the VIE and is most closely associated with the VIE as compared to other interest holders. Therefore, PSNH is considered the primary beneficiary and consolidates PSNH Funding in its consolidated financial statements. The following tables summarize the impact of PSNH Funding on PSNH's balance sheets and income statements:

(Millions of Dollars)
Balance Sheet:	As of December 31, 2019		As of December 31, 2018
Restricted Cash - Current Portion (included in Current Assets)	$	32.5	$	47.5
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2
Securitized Stranded Cost (included in Regulatory Assets)	565.3		608.4
Other Regulatory Liabilities (included in Regulatory Liabilities)	5.6		5.8
Accrued Interest (included in Other Current Liabilities)	8.6		14.4
Rate Reduction Bonds - Current Portion	43.2		52.3
Rate Reduction Bonds - Long-Term Portion	540.1		583.3

(Millions of Dollars) Income Statement:	For the Year Ended December 31, 2019		For the Year Ended December 31, 2018
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	$	43.0	$	27.3
Interest Expense on RRB Principal (included in Interest Expense)	21.1		14.4

Variable Interest Entities - Other: The Company's variable interests outside of the consolidated group include contracts that are required by regulation and provide for regulatory recovery of contract costs and benefits through customer rates.  Eversource, CL&P and NSTAR Electric hold variable interests in VIEs through agreements with certain entities that own single renewable energy or peaking generation power plants, with other independent power producers and with transmission businesses.  Eversource, CL&P and NSTAR Electric do not control the activities that are economically significant to these VIEs or provide financial or other support to these VIEs.  Therefore, Eversource, CL&P and NSTAR Electric do not consolidate these VIEs.

11.     EMPLOYEE BENEFITS

A.     Pension Benefits and Postretirement Benefits Other Than Pension

Eversource provides defined benefit retirement plans (Pension Plans) that cover eligible employees and are subject to the provisions of ERISA, as amended by the Pension Protection Act of 2006. Eversource's policy is to annually fund the Pension Plans in an amount at least equal to an amount that will satisfy all federal funding requirements. In addition to the Pension Plans, Eversource maintains non-qualified defined benefit retirement plans (SERP Plans) which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees.

Eversource also provides defined benefit postretirement plans (PBOP Plans) that provide life insurance and a health reimbursement arrangement created for the purpose of reimbursing retirees and dependents for health insurance premiums and certain medical expenses to eligible employees that meet certain age and service eligibility requirements. The benefits provided under the PBOP Plans are not vested, and the Company has the right to modify any benefit provision subject to applicable laws at that time. Eversource annually funds postretirement costs through tax deductible contributions to external trusts.

The Pension, SERP and PBOP Plans cover eligible employees, including, among others, employees of the regulated companies. Because the regulated companies recover retiree benefit costs from customers through rates, regulatory assets are recorded in lieu of recording an adjustment to Accumulated Other Comprehensive Income/(Loss) as an offset to the funded status of the Pension, SERP and PBOP Plans.  Regulatory accounting is also applied to the portions of the Eversource Service retiree benefit costs that support the regulated companies, as these costs are also recovered from customers.  Adjustments to the Pension, SERP and PBOP Plans' funded status for the unregulated companies are recorded on an after-tax basis to Accumulated Other Comprehensive Income/(Loss).  For further information, see Note 2, "Regulatory Accounting," and Note 17, "Accumulated Other Comprehensive Income/(Loss)," to the financial statements.  

Funded Status:  The Pension, SERP and PBOP Plans are accounted for under the multiple-employer approach, with each operating company's balance sheet reflecting its share of the funded status of the plans.  Although Eversource maintains marketable securities in a benefit trust, the SERP Plans do not contain any assets.  For further information, see Note 5, "Marketable Securities," to the financial statements.  The following tables provide information on the plan benefit obligations, fair values of plan assets, and funded status:  

	Pension and SERP
	As of December 31,
	2019												2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Change in Benefit Obligation:
Benefit Obligation as of Beginning of Year	$	(5,520.0	)	$	(1,160.4	)	$	(1,236.5	)	$	(610.7	)	$	(5,936.5	)	$	(1,275.2	)	$	(1,351.0	)	$	(642.2	)
Service Cost	(67.7		)	(18.0		)	(14.6		)	(7.1		)	(84.8		)	(21.4		)	(17.4		)	(11.2		)
Interest Cost	(219.0		)	(45.7		)	(49.0		)	(24.0		)	(196.4		)	(41.8		)	(43.5		)	(22.0		)
Actuarial Gain/(Loss)	(815.3		)	(176.6		)	(181.0		)	(84.5		)	414.9			106.1			98.6			39.2
Benefits Paid - Pension	273.0			60.2			67.1			30.3			261.8			59.6			66.9			26.2
Benefits Paid - Lump Sum	20.0			—			12.9			—			14.2			—			7.1			—
Benefits Paid - SERP	7.3			0.3			0.1			0.4			6.8			0.3			0.3			0.2
Employee Transfers	—			8.9			3.7			3.0			—			12.0			2.5			(0.9		)
Benefit Obligation as of End of Year	$	(6,321.7	)	$	(1,331.3	)	$	(1,397.3	)	$	(692.6	)	$	(5,520.0	)	$	(1,160.4	)	$	(1,236.5	)	$	(610.7	)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of   Beginning of Year	$	4,573.9		$	918.4		$	1,222.1		$	506.6		$	4,739.5		$	963.0		$	1,260.8		$	539.5
Employer Contributions	112.5			24.0			0.4			15.4			185.6			41.2			56.5			—
Actual Return on Pension Plan Assets	575.2			112.9			150.0			62.9			(75.2		)	(14.2		)	(18.7		)	(7.6		)
Benefits Paid - Pension	(273.0		)	(60.2		)	(67.1		)	(30.3		)	(261.8		)	(59.6		)	(66.9		)	(26.2		)
Benefits Paid - Lump Sum	(20.0		)	—			(12.9		)	—			(14.2		)	—			(7.1		)	—
Employee Transfers	—			(8.9		)	(3.7		)	(3.0		)	—			(12.0		)	(2.5		)	0.9
Fair Value of Pension Plan Assets as of End of Year	$	4,968.6		$	986.2		$	1,288.8		$	551.6		$	4,573.9		$	918.4		$	1,222.1		$	506.6
Funded Status as of December 31st	$	(1,353.1	)	$	(345.1	)	$	(108.5	)	$	(141.0	)	$	(946.1	)	$	(242.0	)	$	(14.4	)	$	(104.1	)

As of December 31, 2019, there was a decrease in the discount rate used to calculate the pension funded status, which resulted in an increase to Eversource's pension liability of $813.1 million, which was partially offset by changes in actual plan experience and changes in other assumptions.

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As of December 31, 2018, there was an increase in the discount rate used to calculate the pension funded status, which resulted in a decrease to Eversource's pension liability of approximately $465 million, which was partially offset by changes in actual plan experience and changes in other assumptions.

The pension and SERP Plans' funded status includes the current portion of the SERP liability totaling $8.7 million and $8.9 million as of December 31, 2019 and 2018, respectively, which is included in Other Current Liabilities on the balance sheets.  

As of December 31, 2019 and 2018, the accumulated benefit obligation for the Pension and SERP Plans is as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	5,963.4	$	1,205.4	$	1,340.8	$	646.7
2018	5,070.8		1,031.0		1,144.7		543.1

	PBOP
	As of December 31,
	2019												2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Change in Benefit Obligation:
Benefit Obligation as of Beginning of Year	$	(841.5	)	$	(161.7	)	$	(246.3	)	$	(91.9	)	$	(948.6	)	$	(178.4	)	$	(278.6	)	$	(101.1	)
Service Cost	(7.8		)	(1.4		)	(1.7		)	(0.7		)	(10.0		)	(1.9		)	(2.0		)	(1.1		)
Interest Cost	(32.7		)	(6.3		)	(9.5		)	(3.4		)	(30.7		)	(5.8		)	(8.7		)	(3.4		)
Actuarial Gain/(Loss)	(67.0		)	(13.4		)	(15.2		)	(3.1		)	102.5			14.4			28.4			8.6
Benefits Paid	50.0			10.8			15.4			5.6			45.3			10.1			14.5			4.9
Employee Transfers	—			(0.7		)	(1.0		)	0.5			—			(0.1		)	0.1			0.2
Benefit Obligation as of End of Year	$	(899.0	)	$	(172.7	)	$	(258.3	)	$	(93.0	)	$	(841.5	)	$	(161.7	)	$	(246.3	)	$	(91.9	)
Change in Plan Assets:
Fair Value of Plan Assets as of Beginning of Year	$	849.6		$	120.6		$	379.1		$	71.2		$	922.2		$	135.9		$	405.5		$	79.0
Actual Return on Plan Assets	127.0			17.1			57.0			10.0			(36.6		)	(5.2		)	(17.4		)	(2.9		)
Employer Contributions	9.3			—			6.0			—			9.3			—			5.2			—
Benefits Paid	(50.0		)	(10.8		)	(15.4		)	(5.6		)	(45.3		)	(10.1		)	(14.5		)	(4.9		)
Employee Transfers	—			(0.6		)	(2.3		)	0.4			—			—			0.3			—
Fair Value of Plan Assets as of End of Year	$	935.9		$	126.3		$	424.4		$	76.0		$	849.6		$	120.6		$	379.1		$	71.2
Funded Status as of December 31st	$	36.9		$	(46.4	)	$	166.1		$	(17.0	)	$	8.1		$	(41.1	)	$	132.8		$	(20.7	)

The Eversource PBOP funded status includes prepaid assets of $62.7 million and $33.4 million recorded in Other Long-Term Assets and liabilities of $25.8 million and $25.3 million included in Accrued Pension, SERP and PBOP on the balance sheets as of December 31, 2019 and 2018, respectively.

As of December 31, 2019, there was a decrease in the discount rate used to calculate the PBOP funded status, which resulted in an increase to the Eversource PBOP liability of $88.6 million. As of December 31, 2018, there was an increase in the discount rate used to calculate the funded status, which resulted in a decrease to the Eversource PBOP liability of approximately $88 million.

The following actuarial assumptions were used in calculating the Pension, SERP and PBOP Plans' year end funded status:

	Pension and SERP							PBOP
	As of December 31,							As of December 31,
		2019			2018			2019			2018
Discount Rate		3.04%	—	3.35%	4.22%	—	4.45%	3.26%	—	3.28%	4.38%	—	4.41%
Compensation/Progression Rate		3.50%	—	4.00%	3.50%	—	4.00%	N/A

For the Eversource Service PBOP Plan, the health care cost trend rate is not applicable. For the Aquarion PBOP Plan, the health care trend rate is a range of 3.5 percent to 6.5 percent, with an ultimate rate of 3.5 percent to 5 percent in 2019 and 2023, for post-65 and pre-65 retirees, respectively.

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Expense:  Eversource charges net periodic benefit expense/(income) for the Pension, SERP and PBOP Plans to its subsidiaries based on the actual participant demographic data for each subsidiary's participants.  The actual investment return in the trust is allocated to each of the subsidiaries annually in proportion to the investment return expected to be earned during the year. The Company utilizes the spot rate methodology to estimate the discount rate for the service and interest cost components of benefit expense, which provides a more precise measurement by matching projected cash flows to the corresponding spot rates on the yield curve.

The components of net periodic benefit expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets for future recovery, are shown below. The service cost component of net periodic benefit expense/(income), less the capitalized portion, is included in Operations and Maintenance expense on the statements of income.  The remaining components of net periodic benefit expense/(income), less the deferred portion, are included in Other Income, Net on the statements of income.  Pension, SERP and PBOP expense reflected in the statements of cash flows for CL&P, NSTAR Electric and PSNH does not include the intercompany allocations or the corresponding capitalized and deferred portion, as these amounts are cash settled on a short-term basis.

	Pension and SERP												PBOP
	For the Year Ended December 31, 2019												For the Year Ended December 31, 2019
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	67.7		$	18.0		$	14.6		$	7.1		$	7.8		$	1.4		$	1.7		$	0.7
Interest Cost	219.0			45.7			49.0			24.0			32.7			6.3			9.5			3.4
Expected Return on Plan Assets	(367.1		)	(73.2		)	(97.1		)	(40.7		)	(66.8		)	(9.2		)	(30.2		)	(5.4		)
Actuarial Loss	143.2			26.9			44.7			10.6			8.3			1.3			3.3			0.3
Prior Service Cost/(Credit)	0.9			—			0.3			—			(23.5		)	1.1			(16.9		)	0.4
Total Net Periodic Benefit Expense/(Income)	$	63.7		$	17.4		$	11.5		$	1.0		$	(41.5	)	$	0.9		$	(32.6	)	$	(0.6	)
Intercompany Allocations	N/A			$	8.5		$	8.0		$	2.3		N/A			$	(0.9	)	$	(1.2	)	$	(0.4	)

	Pension and SERP												PBOP
	For the Year Ended December 31, 2018												For the Year Ended December 31, 2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	84.8		$	21.4		$	17.4		$	11.2		$	10.0		$	1.9		$	2.0		$	1.1
Interest Cost	196.4			41.8			43.5			22.0			30.7			5.8			8.7			3.4
Expected Return on Plan Assets	(391.6		)	(79.1		)	(104.9		)	(43.6		)	(72.4		)	(10.4		)	(32.5		)	(6.0		)
Actuarial Loss	145.7			29.1			41.1			11.6			10.3			1.6			2.3			0.7
Prior Service Cost/(Credit)	4.3			1.1			0.2			0.4			(23.6		)	1.1			(16.9		)	0.5
Total Net Periodic Benefit Expense/(Income)	$	39.6		$	14.3		$	(2.7	)	$	1.6		$	(45.0	)	$	—		$	(36.4	)	$	(0.3	)
Intercompany Allocations	N/A			$	6.1		$	6.5		$	1.9		N/A			$	(1.0	)	$	(1.3	)	$	(0.4	)

	Pension and SERP												PBOP
	For the Year Ended December 31, 2017												For the Year Ended December 31, 2017
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	71.3		$	18.5		$	15.5		$	9.7		$	9.5		$	1.9		$	1.7		$	1.3
Interest Cost	188.0			41.6			42.7			21.2			27.1			5.3			8.7			3.0
Expected Return on Plan Assets	(334.1		)	(71.7		)	(87.6		)	(40.0		)	(63.7		)	(9.7		)	(28.6		)	(5.5		)
Actuarial Loss	135.2			27.7			41.1			11.6			9.1			1.0			3.4			0.6
Prior Service Cost/(Credit)	4.5			1.5			0.6			0.5			(21.6		)	1.1			(17.0		)	0.6
Total Net Periodic Benefit Expense/(Income)	$	64.9		$	17.6		$	12.3		$	3.0		$	(39.6	)	$	(0.4	)	$	(31.8	)	$	—
Intercompany Allocations	N/A			$	9.8		$	9.1		$	3.3		N/A			$	(0.7	)	$	(1.1	)	$	(0.5	)

The following actuarial assumptions were used to calculate Pension, SERP and PBOP expense amounts:

	Pension and SERP									PBOP
	For the Years Ended December 31,									For the Years Ended December 31,
	2019			2018			2017			2019			2018			2017
Discount Rate	2.63%	—	3.55%	3.85%	—	4.62%	3.20%	—	3.90%	3.85%	—	4.65%	3.28%	—	3.94%	3.48%	—	4.64%
Expected Long-Term Rate of Return	8.25%			8.25%			8.25%			8.25%			8.25%			8.25%
Compensation/Progression Rate	3.50%	—	4.00%	3.50%	—	4.00%	3.50%			N/A			N/A			N/A

For the Aquarion Pension and PBOP Plans, the expected long-term rate of return was 7 percent for the years ended December 31, 2019 and 2018. For the Aquarion PBOP Plan, the health care trend rate was a range of 3.5 percent to 6.75 percent for the year ended December 31, 2019, and 7 percent for the year ended December 31, 2018.

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The following is a summary of the changes in plan assets and benefit obligations recognized in Regulatory Assets and Other Comprehensive Income (OCI) as well as amounts in Regulatory Assets and OCI that were reclassified as net periodic benefit expense during the years presented:

	Pension and SERP												PBOP
	Regulatory Assets						OCI						Regulatory Assets						OCI
	For the Years Ended December 31,												For the Years Ended December 31,
(Millions of Dollars)	2019			2018			2019			2018			2019			2018			2019			2018
Actuarial Losses/(Gains) Arising During the Year	$	591.6		$	48.6		$	15.4		$	0.7		$	4.6		$	6.4		$	2.3		$	(1.2	)
Actuarial Losses Reclassified as Net Periodic Benefit Expense	(137.8		)	(140.1		)	(5.4		)	(5.6		)	(8.0		)	(9.9		)	(0.3		)	(0.4		)
Actuarial Losses Securitized as Stranded Costs (1)	—			(36.7		)	—			—			—			(0.8		)	—			—
Prior Service Cost Arising During the Year	—			—			—			—			—			1.3			—			—
Prior Service (Cost)/Credit Reclassified as Net Periodic Benefit (Expense)/Income	(0.7		)	(3.9		)	(0.2		)	(0.4		)	25.1			23.6			(1.6		)	—
Prior Service Cost Securitized as Stranded Costs (1)	—			(0.1		)	—			—			—			(1.3		)	—			—

⁽¹⁾ These amounts were reclassified to securitized regulatory assets in connection with the divestiture of PSNH's generation business. For further information see Note 2, "Regulatory Accounting" to the financial statements.

The following is a summary of the remaining Regulatory Assets and Accumulated Other Comprehensive Income amounts that have not been recognized as components of net periodic benefit expense as of December 31, 2019 and 2018, as well as the amounts that are expected to be recognized as components in 2020:

	Regulatory Assets as of December 31,						Expected 2020 Expense/(Income)			AOCI as of December 31,				Expected 2020 Expense
(Millions of Dollars)	2019			2018						2019		2018
Pension and SERP
Actuarial Loss	$	2,261.4		$	1,807.6		$	190.3		$	90.8	$	80.8	$	7.2
Prior Service Cost	5.6			6.3			0.9			0.9		1.1		0.2
PBOP
Actuarial Loss	$	203.9		$	207.3		$	8.3		$	7.0	$	5.0	$	0.2
Prior Service (Credit)/Cost	(172.5		)	(197.6		)	(21.4		)	1.0		2.6		0.2

The difference between the actual return and calculated expected return on plan assets for the Pension and PBOP Plans is reflected as a component of unamortized actuarial gains or losses, which are recorded in Regulatory Assets or Accumulated Other Comprehensive Income/(Loss). Unamortized actuarial gains or losses are amortized as a component of pension and PBOP expense over the estimated average future employee service period.

Estimated Future Benefit Payments:  The following benefit payments, which reflect expected future service, are expected to be paid by the Pension, SERP and PBOP Plans:

(Millions of Dollars)	2020		2021		2022		2023		2024		2025 - 2029
Pension and SERP	$	320.1	$	328.7	$	337.5	$	346.5	$	352.4	$	1,813.1
PBOP	58.1		57.9		57.3		56.8		56.2		264.7

Eversource Contributions:   Based on the current status of the Pension Plans and federal pension funding requirements, Eversource currently expects to make contributions of $105.0 million in 2020, of which $23.2 million and $19.5 million will be contributed by CL&P and PSNH, respectively.  The remaining $57.3 million is expected to be contributed by other Eversource subsidiaries, primarily Eversource Service. Eversource currently estimates contributing $2.9 million to the PBOP Plans in 2020.

Fair Value of Pension and PBOP Plan Assets:  Pension and PBOP funds are held in external trusts.  Trust assets, including accumulated earnings, must be used exclusively for Pension and PBOP payments.  Eversource's investment strategy for its Pension and PBOP Plans is to maximize the long-term rates of return on these plans' assets within an acceptable level of risk.  The investment strategy for each asset category includes a diversification of asset types, fund strategies and fund managers and it establishes target asset allocations that are routinely reviewed and periodically rebalanced.  PBOP assets are comprised of assets held in the PBOP Plan trust, as well as specific assets within the Pension Plan trust (401(h) assets).  The investment policy and strategy of the 401(h) assets is consistent with that of the defined benefit pension plan. Eversource's expected long-term rates of return on Pension and PBOP Plan assets are based on target asset allocation assumptions and related expected long-term rates of return.  In developing its expected long-term rate of return assumptions for the Pension and PBOP Plans, Eversource evaluated input from consultants, as well as long-term inflation assumptions and historical returns. Management has assumed long-term rates of return of 8.25 percent for the Eversource Service Pension and PBOP Plan assets and a 7 percent long-term rate of return for the Aquarion Plans to estimate its 2020 Pension and PBOP costs.

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These long-term rates of return are based on the assumed rates of return for the target asset allocations as follows:

	As of December 31,
	2019				2018
	Eversource Pension Plan and Tax-Exempt Assets Within PBOP Plan				Eversource Pension Plan and Tax-Exempt Assets Within PBOP Plan
	Target Asset Allocation		Assumed Rate of Return		Target Asset Allocation		Assumed Rate of Return
Equity Securities:
United States	15.0	%	8.5	%	15.0	%	8.5	%
Global	10.0	%	8.75	%	10.0	%	8.75	%
Non-United States	8.0	%	8.5	%	8.0	%	8.5	%
Emerging Markets	4.0	%	10.0	%	4.0	%	10.0	%
Debt Securities:
Fixed Income	13.0	%	4.0	%	13.0	%	4.0	%
Public High Yield Fixed Income	4.0	%	6.5	%	4.0	%	6.5	%
Private Debt	15.0	%	9.0	%	15.0	%	9.0	%
Private Equity	15.0	%	12.0	%	15.0	%	12.0	%
Real Assets	16.0	%	7.5	%	16.0	%	7.5	%

The taxable assets within the Eversource PBOP Plan have a target asset allocation of 70 percent equity securities and 30 percent fixed income securities. The target asset allocation for the Aquarion Pension Plan is 54 percent equity, 36 percent debt and 10 percent other. The target asset allocation for the Aquarion PBOP Plan is 54 percent equity, 41 percent debt and 5 percent other.

The following table presents, by asset category, the Pension and PBOP Plan assets recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:  

	Pension Plan
	Fair Value Measurements as of December 31,
(Millions of Dollars)	2019									2018
Asset Category:	Level 1		Level 2		Uncategorized		Total			Level 1		Level 2		Uncategorized		Total
Equity Securities (1)	$	592.6	$	—	$	1,349.9	$	1,942.5		$	443.4	$	—	$	1,377.8	$	1,821.2
Fixed Income (2)	99.4		303.0		1,222.8		1,625.2			85.5		160.8		1,265.5		1,511.8
Private Equity	16.9		—		971.4		988.3			6.1		—		834.0		840.1
Real Assets (3)	58.7		—		615.0		673.7			62.9		—		569.1		632.0
Total	$	767.6	$	303.0	$	4,159.1	$	5,229.7		$	597.9	$	160.8	$	4,046.4	$	4,805.1
Less:  401(h) PBOP Assets (4)							(261.1		)							(231.2		)
Total Pension Assets							$	4,968.6								$	4,573.9

	PBOP Plan
	Fair Value Measurements as of December 31,
(Millions of Dollars)	2019								2018
Asset Category:	Level 1		Level 2		Uncategorized		Total		Level 1		Level 2		Uncategorized		Total
Equity Securities (1)	$	158.0	$	—	$	187.0	$	345.0	$	91.9	$	—	$	210.5	$	302.4
Fixed Income (2)	15.8		39.6		148.1		203.5		22.0		40.3		123.0		185.3
Private Equity	—		—		26.5		26.5		—		—		32.7		32.7
Real Assets (3)	51.2		—		48.6		99.8		27.5		—		70.5		98.0
Total	$	225.0	$	39.6	$	410.2	$	674.8	$	141.4	$	40.3	$	436.7	$	618.4
Add:  401(h) PBOP Assets (4)							261.1								231.2
Total PBOP Assets							$	935.9							$	849.6

⁽¹⁾   United States, Global, Non-United States and Emerging Markets equity securities that are uncategorized include investments in commingled funds and hedge funds that are overlaid with equity index swaps and futures contracts.

⁽²⁾ Fixed Income investments that are uncategorized include investments in commingled funds, fixed income funds that invest in a variety of opportunistic and fixed income strategies, and hedge funds that are overlaid with fixed income futures.  

⁽³⁾   Real assets include real estate funds and hedge funds.

⁽⁴⁾   The assets of the Pension Plan include a 401(h) account that has been allocated to provide health and welfare postretirement benefits under the PBOP Plan.

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The Company values assets based on observable inputs when available.  Equity securities, exchange traded funds and futures contracts classified as Level 1 in the fair value hierarchy are priced based on the closing price on the primary exchange as of the balance sheet date.

Fixed income securities, such as government issued securities and corporate bonds, are included in Level 2 and are valued using pricing models, quoted prices of securities with similar characteristics or discounted cash flows.  The pricing models utilize observable inputs such as recent trades for the same or similar instruments, yield curves, discount margins and bond structures. Swaps are valued using pricing models that incorporate interest rates and equity and fixed income index closing prices to determine a net present value of the cash flows.  

Certain investments, such as commingled funds, private equity investments, real estate funds and hedge funds are valued using the net asset value (NAV) as a practical expedient. These investments are structured as investment companies offering shares or units to multiple investors for the purpose of providing a return. Commingled funds are recorded at NAV provided by the asset manager, which is based on the market prices of the underlying equity securities.  Private Equity investments, Fixed Income partnership funds and Real Assets are valued using the NAV provided by the partnerships, which are based on discounted cash flows of the underlying investments, real estate appraisals or public market comparables of the underlying investments, or the NAV of underlying assets held in hedge funds. Assets valued at NAV are uncategorized in the fair value hierarchy.

B.     Defined Contribution Plans

Eversource maintains defined contribution plans on behalf of eligible participants.  The Eversource 401k Plan provides for employee and employer contributions up to statutory limits.  For eligible employees, the Eversource 401k Plan provides employer matching contributions of either 100 percent up to a maximum of three percent of eligible compensation or 50 percent up to a maximum of eight percent of eligible compensation. The Eversource 401k Plan also contains a K-Vantage feature for the benefit of eligible participants, which provides an additional annual employer contribution based on age and years of service.  K-Vantage participants are not eligible to actively participate in the Eversource Pension Plan.

The total Eversource 401k Plan employer matching contributions, including the K-Vantage contributions, were as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	41.6	$	5.5	$	10.3	$	3.5
2018	38.4		5.0		9.7		3.3
2017	34.5		4.6		8.5		3.7

C.    Share-Based Payments

Share-based compensation awards are recorded using a fair-value based method at the date of grant.  Eversource, CL&P, NSTAR Electric and PSNH record compensation expense related to these awards, as applicable, for shares issued or sold to their respective employees and officers, as well as for the allocation of costs associated with shares issued or sold to Eversource's service company employees and officers that support CL&P, NSTAR Electric and PSNH.  

Eversource Incentive Plans:  Eversource maintains long-term equity-based incentive plans in which Eversource, CL&P, NSTAR Electric and PSNH employees, officers and board members are eligible to participate.  The incentive plans authorize Eversource to grant up to 6,700,000 new shares for various types of awards, including RSUs and performance shares, to eligible employees, officers, and board members. As of December 31, 2019 and 2018, Eversource had 3,302,526 and 3,720,650 common shares, respectively, available for issuance under these plans.

Eversource accounts for its various share-based plans as follows:

• RSUs - Eversource records compensation expense, net of estimated forfeitures, on a straight-line basis over the requisite service period based upon the fair value of Eversource's common shares at the date of grant.  The par value of RSUs is reclassified to Common Stock from Capital Surplus, Paid In as RSUs become issued as common shares.

• Performance Shares - Eversource records compensation expense, net of estimated forfeitures, on a straight-line basis over the requisite service period.  Performance shares vest based upon the extent to which Company goals are achieved.  Vesting of outstanding performance shares is based upon both the Company's EPS growth over the requisite service period and the total shareholder return as compared to the Edison Electric Institute (EEI) Index during the requisite service period.  The fair value of performance shares is determined at the date of grant using a lattice model.

RSUs:  Eversource granted RSUs under the annual long-term incentive programs that are subject to three-year graded vesting schedules for employees, and one-year graded vesting schedules, or immediate vesting, for board members.  RSUs are paid in shares, reduced by amounts sufficient to satisfy withholdings for income taxes, subsequent to vesting.  A summary of RSU transactions is as follows:

	RSUs (Units)		Weighted Average Grant-Date Fair Value
Outstanding as of December 31, 2018	782,365		$	50.25
Granted	271,144		$	67.91
Shares Issued	(263,219	)	$	55.34
Forfeited	(16,127	)	$	63.31
Outstanding as of December 31, 2019	774,163		$	54.43

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The weighted average grant-date fair value of RSUs granted for the years ended December 31, 2019, 2018 and 2017 was $67.91, $56.69 and $55.97, respectively.  As of December 31, 2019 and 2018, the number and weighted average grant-date fair value of unvested RSUs was 439,293 and $63.06 per share, and 424,119 and $56.57 per share, respectively.  During 2019, there were 236,359 RSUs at a weighted average grant-date fair value of $57.47 per share that vested during the year and were either paid or deferred.  As of December 31, 2019, 334,870 RSUs were fully vested and deferred and an additional 417,328 are expected to vest.  

Performance Shares:  Eversource granted performance shares under the annual long-term incentive programs that vest based upon the extent to which Company goals are achieved at the end of three-year performance measurement periods.  Performance shares are paid in shares, after the performance measurement period.  A summary of performance share transactions is as follows:

	Performance Shares (Units)		Weighted Average Grant-Date Fair Value
Outstanding as of December 31, 2018	499,564		$	56.08
Granted	165,022		$	68.33
Shares Issued	(162,959	)	$	55.69
Forfeited	(14,720	)	$	58.20
Outstanding as of December 31, 2019	486,907		$	60.30

The weighted average grant-date fair value of performance shares granted for the years ended December 31, 2019, 2018 and 2017 was $68.33, $56.77 and $55.70, respectively.  As of December 31, 2019 and 2018, the number and weighted average grant-date fair value of unvested performance shares was 427,894 and $60.38 per share, and 366,995 and $56.17 per share, respectively.  During 2019, there were 88,664 performance shares at a weighted average grant-date fair value of $58.13 per share that vested during the year and were either paid or deferred.  As of December 31, 2019, 59,013 performance shares were fully vested and deferred.

Compensation Expense: The total compensation expense and associated future income tax benefits recognized by Eversource, CL&P, NSTAR Electric and PSNH for share-based compensation awards were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Compensation Expense	$	27.3	$	21.4	$	19.7
Future Income Tax Benefit	7.0		5.4		8.0

	For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Compensation Expense	$	9.8	$	9.7	$	3.3	$	7.8	$	7.7	$	2.9	$	7.0	$	7.0	$	3.2
Future Income Tax Benefit	2.5		2.5		0.8		2.0		1.9		0.7		2.9		2.8		1.3

As of December 31, 2019, there was $24.4 million of total unrecognized compensation expense related to nonvested share-based awards for Eversource, including $5.3 million for CL&P, $5.3 million for NSTAR Electric and $2.1 million for PSNH.  This cost is expected to be recognized ratably over a weighted-average period of 1.75 years for Eversource, 1.79 years for CL&P and NSTAR Electric, and 1.78 years for PSNH.

An income tax rate of 25 percent was used to estimate the tax effect on total share-based payments determined under the fair-value based method for all awards.  Beginning in 2019, the Company began issuing treasury shares to settle fully vested RSUs and performance shares under the Company's incentive plans.

For the years ended December 31, 2019, 2018 and 2017, excess tax benefits associated with the distribution of stock compensation awards reduced income tax expense by $1.5 million, $1.5 million, and $2.9 million, respectively, which increased cash flows from operating activities on the statements of cash flows.

D.     Other Retirement Benefits

Eversource provides retirement and other benefits for certain current and past company officers.  These benefits are accounted for on an accrual basis and expensed over a period equal to the service lives of the employees.  The actuarially-determined liability for these benefits is included in Other Current and Long-Term Liabilities on the balance sheets. The related expense, which includes the allocation of expense associated with Eversource's service company officers that support CL&P, NSTAR Electric and PSNH, is included in Operations and Maintenance Expense on the income statements. The liability and expense amounts are as follows:

Eversource (Millions of Dollars)	As of and For the Years Ended December 31,
	2019		2018		2017
Actuarially-Determined Liability	$	52.0	$	49.1	$	53.4
Other Retirement Benefits Expense	2.7		2.7		2.8

101

	As of and For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Actuarially-Determined   Liability	$	0.2	$	0.1	$	1.7	$	0.3	$	0.1	$	1.7	$	0.3	$	0.1	$	1.9
Other Retirement Benefits   Expense	1.0		0.9		0.4		1.1		1.1		0.4		1.0		1.0		0.5

12.     INCOME TAXES

The components of income tax expense are as follows:

Eversource (Millions of Dollars)	For the Years Ended December 31,
	2019			2018			2017
Current Income Taxes:
Federal	$	56.9		$	106.5		$	58.9
State	10.5			10.6			31.6
Total Current	67.4			117.1			90.5
Deferred Income Taxes, Net:
Federal	138.4			122.6			433.0
State	71.4			52.2			58.6
Total Deferred	209.8			174.8			491.6
Investment Tax Credits, Net	(3.7		)	(2.9		)	(3.2		)
Income Tax Expense	$	273.5		$	289.0		$	578.9

	For the Years Ended December 31,
	2019								2018									2017
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH		CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Current Income Taxes:
Federal	$	68.4		$	82.6		$	22.9	$	54.2		$	79.3		$	12.2		$	50.9		$	107.8		$	18.6
State	15.4			18.2			2.2		20.9			30.0			(0.5		)	17.4			25.6			6.2
Total Current	83.8			100.8			25.1		75.1			109.3			11.7			68.3			133.4			24.8
Deferred Income Taxes, Net:
Federal	35.2			0.1			5.8		48.5			27.9			15.4			123.9			88.1			52.7
State	18.8			27.0			10.1		6.4			13.5			20.5			(4.6		)	22.4			11.2
Total Deferred	54.0			27.1			15.9		54.9			41.4			35.9			119.3			110.5			63.9
Investment Tax Credits, Net	(0.8		)	(2.6		)	—		(0.9		)	(1.8		)	—			(1.0		)	(1.8		)	—
Income Tax Expense	$	137.0		$	125.3		$	41.0	$	129.1		$	148.9		$	47.6		$	186.6		$	242.1		$	88.7

A reconciliation between income tax expense and the expected tax expense at the statutory rate is as follows:

Eversource (Millions of Dollars, except percentages)	For the Years Ended December 31,
	2019			2018			2017
Income Before Income Tax Expense	$	1,190.1		$	1,329.5		$	1,574.4
Statutory Federal Income Tax Expense at 21% in 2019 and 2018,   and 35% in 2017	249.9			279.2			551.0
Tax Effect of Differences:
Depreciation	1.9			(30.8		)	(10.8		)
Investment Tax Credit Amortization	(3.7		)	(2.9		)	(3.2		)
State Income Taxes, Net of Federal Impact	24.6			44.4			47.7
Dividends on ESOP	(5.1		)	(5.1		)	(8.4		)
Tax Asset Valuation Allowance/Reserve Adjustments	40.1			5.2			7.0
Excess Stock Benefit	(1.5		)	(1.5		)	(2.9		)
EDIT Amortization	(37.4		)	(5.0		)	—
Other, Net	4.7			5.5			(1.5		)
Income Tax Expense	$	273.5		$	289.0		$	578.9
Effective Tax Rate	23.0		%	21.7		%	36.8		%

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	For the Years Ended December 31,
	2019									2018									2017
(Millions of Dollars, except percentages)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Income Before Income Tax Expense	$	547.8		$	557.3		$	175.0		$	506.8		$	532.0		$	163.5		$	563.4		$	616.8		$	224.7
Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017	115.0			117.0			36.8			106.4			111.7			34.3			197.2			215.9			78.6
Tax Effect of Differences:
Depreciation	(0.2		)	(3.0		)	(0.8		)	(1.2		)	(2.8		)	0.1			(5.2		)	(3.0		)	1.1
Investment Tax Credit Amortization	(0.8		)	(2.6		)	—			(0.9		)	(1.8		)	—			(1.0		)	(1.8		)	—
State Income Taxes,   Net of Federal Impact	2.5			35.7			9.8			14.5			33.2			15.8			4.5			31.2			11.3
Tax Asset Valuation   Allowance/Reserve Adjustments	24.5			—			—			7.1			1.2			—			(9.5		)	—			—
Excess Stock Benefit	(0.5		)	(0.5		)	(0.2		)	(0.1		)	(0.1		)	(0.1		)	(0.7		)	(0.7		)	(0.3		)
EDIT Amortization	(5.8		)	(22.9		)	(4.0		)	—			—			(4.4		)	—			—			—
Other, Net	2.3			1.6			(0.6		)	3.3			7.5			1.9			1.3			0.5			(2.0		)
Income Tax Expense	$	137.0		$	125.3		$	41.0		$	129.1		$	148.9		$	47.6		$	186.6		$	242.1		$	88.7
Effective Tax Rate	25.0		%	22.5		%	23.4		%	25.5		%	28.0		%	29.1		%	33.1		%	39.2		%	39.5		%

Eversource, CL&P, NSTAR Electric and PSNH file a consolidated federal income tax return and unitary, combined and separate state income tax returns.  These entities are also parties to a tax allocation agreement under which taxable subsidiaries do not pay any more taxes than they would have otherwise paid had they filed a separate company tax return, and subsidiaries generating tax losses, if any, are paid for their losses when utilized.

Deferred tax assets and liabilities are recognized for the future tax effects of temporary differences between the carrying amounts and the tax basis of assets and liabilities.  The tax effect of temporary differences is accounted for in accordance with the rate-making treatment of the applicable regulatory commissions and relevant accounting authoritative literature.  The tax effects of temporary differences that give rise to the net accumulated deferred income tax obligations are as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Deferred Tax Assets:
Employee Benefits	$	509.4	$	125.4	$	54.8	$	46.7	$	388.2	$	94.5	$	35.0	$	31.1
Derivative Liabilities	105.0		103.6		—		—		111.4		111.4		—		—
Regulatory Deferrals - Liabilities	267.0		37.1		165.7		19.0		299.3		38.6		195.5		16.1
Allowance for Uncollectible Accounts	56.7		25.7		17.7		2.8		54.0		23.1		17.8		3.0
Tax Effect - Tax Regulatory Liabilities	830.4		333.5		280.9		111.3		830.3		336.8		288.9		111.7
Net Operating Loss Carryforwards	9.1		—		—		—		28.5		—		—		0.6
Purchase Accounting Adjustment	58.7		—		—		—		64.2		—		—		—
Other	190.4		92.0		35.8		20.0		166.2		81.1		15.6		33.4
Total Deferred Tax Assets	2,026.7		717.3		554.9		199.8		1,942.1		685.5		552.8		195.9
Less:  Valuation Allowance	43.0		24.9		—		—		19.5		10.7		—		—
Net Deferred Tax Assets	$	1,983.7	$	692.4	$	554.9	$	199.8	$	1,922.6	$	674.8	$	552.8	$	195.9
Deferred Tax Liabilities:
Accelerated Depreciation and Other   Plant-Related Differences	$	3,901.0	$	1,362.2	$	1,391.9	$	428.9	$	3,724.2	$	1,293.3	$	1,342.4	$	410.6
Property Tax Accruals	76.8		36.8		29.0		4.7		73.2		35.4		26.3		5.2
Regulatory Amounts:
Regulatory Deferrals - Assets	1,155.6		340.7		276.2		260.9		1,025.9		320.1		277.4		213.8
Tax Effect - Tax Regulatory Assets	238.2		171.7		11.7		8.3		238.9		167.0		9.7		8.1
Goodwill Regulatory Asset - 1999 Merger	90.6		—		77.8		—		95.2		—		81.7		—
Derivative Assets	19.7		19.7		—		—		20.1		19.9		—		—
Other	257.6		5.9		125.6		3.2		251.1		5.9		109.8		39.4
Total Deferred Tax Liabilities	$	5,739.5	$	1,937.0	$	1,912.2	$	706.0	$	5,428.6	$	1,841.6	$	1,847.3	$	677.1

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2017 Federal Legislation: On December 22, 2017, the Tax Cuts and Jobs Act became law, which amended existing federal tax rules and included numerous provisions that impacted corporations.  In particular, the act reduced the U.S. federal corporate income tax rate from 35 percent to 21 percent effective January 1, 2018.  For our regulated companies, the most significant changes are (1) the benefit of incurring a lower federal income tax expense and (2) the reduction in ADIT liabilities (now excess ADIT or EDIT), which are estimated to be approximately $2.8 billion and are included in regulatory liabilities as of December 31, 2019. In 2019, Eversource refunded $51.5 million ($7.9 million at CL&P, $31.5 million at NSTAR Electric, $5.6 million at PSNH, $1.4 million at Yankee Gas and $5.1 million at NSTAR Gas) to customers. See Note 2, "Regulatory Accounting," to the financial statements for further information.

2019 Federal Legislation:  On December 20, 2019, the "Further Consolidated Appropriations Act, 2020," became law, which provided a one-year extension of the production tax credit or the investment tax credit for renewable wind projects under Section 45 of the Internal Revenue Code of 1986 on which construction begins before January 1, 2021. If construction begins on a qualifying wind project in 2020, the project will qualify for a production tax credit of $15 per MWh or an 18 percent investment tax credit. 

Carryforwards:  The following table provides the amounts and expiration dates of state tax credit and loss carryforwards and federal tax credit and net operating loss carryforwards:

	As of December 31,
	2019									2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Expiration Range	Eversource		CL&P		NSTAR Electric		PSNH		Expiration Range
Federal Net Operating Loss	$	19.8	$	—	$	—	$	—	2033 - 2037	$	103.6	$	—	$	—	$	—	2033 - 2037
Federal Charitable Contribution	—		—		—		—		2020 - 2022	2.2		—		—		—		2020 - 2022
State Net   Operating Loss	65.5		—		—		—		2020 - 2038	80.7		—		—		—		2019 - 2038
State Tax Credit	168.1		122.3		—		—		2019 - 2024	148.9		107.0		—		—		2018 - 2023
State Charitable Contribution	9.9		—		—		—		2019 - 2023	9.6		—		—		—		2019 - 2023

In 2019, the company increased its valuation allowance reserve for state credits by $18.5 million ($14.2 million for CL&P), net of tax, to reflect an update for expired tax credits. In 2018, the Company increased its valuation allowance reserve for state credits by $5.2 million ($4.4 million for CL&P), net of tax, to reflect an update for expired tax credits.

For 2019 and 2018, state credit and state loss carryforwards have been partially reserved by a valuation allowance of $43.0 million and $19.5 million (net of tax), respectively.  

Unrecognized Tax Benefits:  A reconciliation of the activity in unrecognized tax benefits, all of which would impact the effective tax rate if recognized, is as follows:

(Millions of Dollars)	Eversource			CL&P
Balance as of January 1, 2017	$	48.4		$	15.3
Gross Increases - Current Year	11.4			4.7
Gross Decreases - Prior Year	(0.9		)	(0.5		)
Lapse of Statute of Limitations	(7.2		)	(1.4		)
Balance as of December 31, 2017	51.7			18.1
Gross Increases - Current Year	9.2			3.2
Gross Decreases - Prior Year	(6.5		)	(0.9		)
Lapse of Statute of Limitations	(8.5		)	(2.2		)
Balance as of December 31, 2018	45.9			18.2
Gross Increases - Current Year	12.1			4.0
Gross Increases - Prior Year	3.4			3.3
Lapse of Statute of Limitations	(6.4		)	(2.4		)
Balance as of December 31, 2019	$	55.0		$	23.1

Interest and Penalties:  Interest on uncertain tax positions is recorded and generally classified as a component of Other Interest Expense on the statements of income.  However, when resolution of uncertainties results in the Company receiving interest income, any related interest benefit is recorded in Other Income, Net on the statements of income.  No penalties have been recorded.  The amount of interest expense/(income) on uncertain tax positions recognized and the related accrued interest payable/(receivable) are as follows:  

	Other Interest Expense/(Income)							Accrued Interest Expense
	For the Years Ended December 31,							As of December 31,
(Millions of Dollars)	2019		2018			2017		2019		2018
Eversource	$	—	$	(1.7	)	$	—	$	0.1	$	0.1

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Tax Positions:  During 2019 and 2018, Eversource did not resolve any of its uncertain tax positions.

Open Tax Years:  The following table summarizes Eversource, CL&P, NSTAR Electric and PSNH's tax years that remain subject to examination by major tax jurisdictions as of December 31, 2019:

Description	Tax Years
Federal	2019
Connecticut	2016 - 2019
Massachusetts	2016 - 2019
New Hampshire	2017 - 2019

Eversource does not estimate to have an earnings impact related to unrecognized tax benefits during the next twelve months.

13.     COMMITMENTS AND CONTINGENCIES

A.     Environmental Matters

Eversource, CL&P, NSTAR Electric and PSNH are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment.  These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites. Eversource, CL&P, NSTAR Electric and PSNH have an active environmental auditing and training program and each believes it is substantially in compliance with all enacted laws and regulations.

Environmental reserves are accrued when assessments indicate it is probable that a liability has been incurred and an amount can be reasonably estimated.  The approach used estimates the liability based on the most likely action plan from a variety of available remediation options, including no action required or several different remedies ranging from establishing institutional controls to full site remediation and monitoring.  These liabilities are estimated on an undiscounted basis and do not assume that the amounts are recoverable from insurance companies or other third parties.  The environmental reserves include sites at different stages of discovery and remediation and do not include any unasserted claims.

These reserve estimates are subjective in nature as they take into consideration several different remediation options at each specific site.  The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource's, CL&P's, NSTAR Electric's and PSNH's responsibility for remediation or the extent of remediation required, recently enacted laws and regulations or changes in cost estimates due to certain economic factors. It is possible that new information or future developments could require a reassessment of the potential exposure to required environmental remediation.  As this information becomes available, management will continue to assess the potential exposure and adjust the reserves accordingly.  

The amounts recorded as environmental reserves are included in Other Current Liabilities and Other Long-Term Liabilities on the balance sheets and represent management's best estimate of the liability for environmental costs, and take into consideration site assessment, remediation and long-term monitoring costs.  The environmental reserves also take into account recurring costs of managing hazardous substances and pollutants, mandated expenditures to remediate contaminated sites and any other infrequent and non-recurring clean-up costs.  A reconciliation of the activity in the environmental reserves is as follows:

(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH
Balance as of January 1, 2018	$	54.9		$	4.7		$	2.7		$	5.7
Additions	23.5			1.9			9.7			—
Payments/Reductions	(13.7		)	(1.2		)	(1.5		)	(0.3		)
Balance as of December 31, 2018	64.7			5.4			10.9			5.4
Additions	26.5			7.0			0.5			2.8
Payments/Reductions	(10.2		)	(1.0		)	(3.4		)	(0.7		)
Balance as of December 31, 2019	$	81.0		$	11.4		$	8.0		$	7.5

The number of environmental sites for which remediation or long-term monitoring, preliminary site work or site assessment is being performed are as follows:

	Eversource	CL&P	NSTAR Electric	PSNH
2019	57	15	15	9
2018	60	15	16	9

The increase in the reserve balance was due primarily to changes in cost estimates at certain MGP sites at the natural gas companies, at CL&P and at PSNH, for which additional remediation will be required.

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Included in the number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured natural gas from coal and other processes, which resulted in certain by-products remaining in the environment that may pose a potential risk to human health and the environment, for which Eversource may have potential liability.  The reserve balances related to these former MGP sites were $67.9 million and $50.1 million as of December 31, 2019 and 2018, respectively, and related primarily to the natural gas business segment.

As of December 31, 2019, for 6 environmental sites (1 for CL&P) that are included in the Company's reserve for environmental costs, the information known and the nature of the remediation options allow for the Company to estimate the range of losses for environmental costs.  As of December 31, 2019, $35.9 million (including $0.4 million for CL&P) had been accrued as a liability for these sites, which represents the low end of the range of the liabilities for environmental costs.  Management believes that additional losses of up to approximately $35 million ($0.5 million at CL&P) may be incurred in executing current remediation plans for these sites.  

As of December 31, 2019, for 15 environmental sites (7 for CL&P and 4 for NSTAR Electric) that are included in the Company's reserve for environmental costs, management cannot reasonably estimate the exposure to loss in excess of the reserve, or range of loss, as these sites are under investigation and/or there is significant uncertainty as to what remedial actions, if any, the Company may be required to undertake.  As of December 31, 2019, $7.4 million (including $2.3 million for CL&P and $1.9 million for NSTAR Electric) had been accrued as a liability for these sites.  As of December 31, 2019, for the remaining 36 environmental sites (including 7 for CL&P, 11 for NSTAR Electric and 9 for PSNH) that are included in the Company's reserve for environmental costs, the $37.7 million accrual (including $8.7 million for CL&P, $6.1 million for NSTAR Electric and $7.5 million for PSNH) represents management's best estimate of the probable liability and no additional loss is anticipated at this time.

PSNH, NSTAR Gas and Yankee Gas have rate recovery mechanisms for MGP related environmental costs, therefore, changes in their respective environmental reserves do not impact Net Income. CL&P is allowed to defer certain environmental costs for future recovery.  NSTAR Electric does not have a separate environmental cost recovery regulatory mechanism.

B.     Long-Term Contractual Arrangements

Estimated Future Annual Costs:  The estimated future annual costs of significant executed, non-cancelable, long-term contractual arrangements in effect as of December 31, 2019 are as follows:

Eversource
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	614.6	$	594.3	$	651.7	$	629.1	$	624.8	$	3,590.6	$	6,705.1
Purchased Power and Capacity	73.5		69.0		75.1		81.6		75.9		71.5		446.6
Peaker CfDs	22.4		23.0		16.9		20.1		15.5		29.8		127.7
Natural Gas Procurement	266.2		255.3		202.8		166.7		165.7		1,093.3		2,150.0
Transmission Support Commitments	22.1		—		—		—		—		—		22.1
Total	$	998.8	$	941.6	$	946.5	$	897.5	$	881.9	$	4,785.2	$	9,451.5

CL&P
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	457.3	$	459.6	$	514.4	$	516.2	517.4		2,790.6		$	5,255.5
Purchased Power and Capacity	69.8		65.3		71.4		78.0		72.9		55.5		412.9
Peaker CfDs	22.4		23.0		16.9		20.1		15.5		29.8		127.7
Transmission Support Commitments	8.7		—		—		—		—		—		8.7
Total	$	558.2	$	547.9	$	602.7	$	614.3	$	605.8	$	2,875.9	$	5,804.8

NSTAR Electric
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	95.5	$	91.2	$	91.4	$	66.6	$	63.8	$	418.1	$	826.6
Purchased Power and Capacity	3.1		3.1		3.1		3.0		3.0		16.0		31.3
Transmission Support Commitments	8.7		—		—		—		—		—		8.7
Total	$	107.3	$	94.3	$	94.5	$	69.6	$	66.8	$	434.1	$	866.6

PSNH
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	61.8	$	43.5	$	45.9	$	46.3	$	43.6	$	381.9	$	623.0
Purchased Power and Capacity	0.6		0.6		0.6		0.6		—		—		2.4
Transmission Support Commitments	4.7		—		—		—		—		—		4.7
Total	$	67.1	$	44.1	$	46.5	$	46.9	$	43.6	$	381.9	$	630.1

Renewable Energy:  Renewable energy contracts include non-cancellable commitments under contracts of CL&P, NSTAR Electric and PSNH for the purchase of energy and capacity from renewable energy facilities.  Such contracts extend through 2039 for CL&P, 2040 for NSTAR Electric and 2033 for PSNH.

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On December 28, 2018, under Public Act 17-3, "An Act Concerning Zero Carbon Procurement," DEEP selected the Millstone Nuclear Power Station generation facility and Seabrook Nuclear Power Plant, along with smaller generation facilities, in DEEP’s zero-carbon request for proposal. CL&P and UI were directed by DEEP to enter into ten-year contracts to purchase a combined total of approximately 9 million MWh annually from the Millstone generation facility. On March 15, 2019, CL&P and UI each signed a ten-year contract with the owner of Millstone Nuclear Power Station in order to purchase a combined amount of approximately 50 percent of the facility's output (approximately 40 percent by CL&P). The Millstone Nuclear Power Station has a 2,112 MW nameplate capacity. PURA approved the contracts on September 18, 2019. Energy deliveries and payments under these contracts began in the fourth quarter of 2019.

CL&P and UI were also directed by DEEP to enter into eight-year contracts to purchase a combined amount of approximately 18 percent of the facility's output (approximately 15 percent by CL&P), from the Seabrook Nuclear Power Plant beginning January 1, 2022. The Seabrook Nuclear Power Plant has an approximate 1,250 MW nameplate capacity. On November 22, 2019, CL&P and UI each signed an eight-year contract with the owner of the Seabrook Nuclear Power Plant. PURA approved the contracts on November 27, 2019.

The total estimated cost of the Millstone Nuclear Power Station and Seabrook Nuclear Power Plant energy purchase contracts are $4.1 billion and are reflected in the table above. CL&P sells the energy purchased under these contracts into the market and uses the proceeds from these energy sales to offset the contract costs.  As the net costs under these contracts are recovered from customers in future rates, the contracts do not have an impact on the net income of CL&P. These new contracts do not meet the definition of a derivative, and accordingly, the costs of these contracts are being accounted for as incurred.

The contractual obligations table above does not include long-term commitments signed by CL&P and NSTAR Electric, as required by the PURA and DPU, respectively, for the purchase of renewable energy and related products that are contingent on the future construction of energy facilities.

Purchased Power and Capacity:  These contracts include capacity CfDs of CL&P through 2026, and various IPP contracts or purchase obligations for electricity which extend through 2024 for CL&P, 2031 for NSTAR Electric and 2023 for PSNH.

CL&P, along with UI, has three capacity CfDs for a total of approximately 676 MW of capacity consisting of two generation units and one demand response project.  The capacity CfDs extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set contractual capacity price and the capacity market prices received by the generation facilities in the ISO-NE capacity markets.  CL&P has a sharing agreement with UI, whereby UI shares 20 percent of the costs and benefits of these contracts.  CL&P's portion of the costs and benefits of these contracts will be paid by, or refunded to, CL&P's customers.  

The contractual obligations table above does not include CL&P's, NSTAR Electric's or PSNH's standard/basic service contracts for the purchase of energy supply, the amounts of which vary with customers' energy needs.

Peaker CfDs:  CL&P, along with UI, has three peaker CfDs for a total of approximately 500 MW of peaking capacity through 2042.  CL&P has a sharing agreement with UI, whereby CL&P is responsible for 80 percent and UI for 20 percent of the net costs or benefits of these CfDs.  The Peaker CfDs pay the generation facility owner the difference between capacity, forward reserve and energy market revenues and a cost-of-service payment stream for 30 years.  The ultimate cost or benefit to CL&P under these contracts will depend on the costs of plant operation and the prices that the projects receive for capacity and other products in the ISO-NE markets.  CL&P's portion of the amounts paid or received under the Peaker CfDs will be recoverable from, or refunded to, CL&P's customers.  

Natural Gas Procurement:  Eversource's natural gas distribution businesses have long-term contracts for the purchase, transportation and storage of natural gas as part of its portfolio of supplies, which extend through 2038.  

Transmission Support Commitments:  Along with other New England utilities, CL&P, NSTAR Electric and PSNH entered into agreements in 1985 to support transmission and terminal facilities that were built to import electricity from the Hydro-Québec system in Canada. CL&P, NSTAR Electric and PSNH are obligated to pay, over a 30-year period ending in 2020, their proportionate shares of the annual operation and maintenance expenses and capital costs of those facilities. Future transmission support agreements beginning in the second half of 2020 are under negotiation.

The total costs incurred under these agreements were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Renewable Energy	$	320.8	$	218.5	$	235.5
Purchased Power and Capacity	62.1		72.0		103.9
Peaker CfDs	13.0		20.9		38.7
Natural Gas Procurement	448.5		432.4		377.0
Transmission Support Commitments	21.8		23.4		19.8
Coal, Wood and Other (1)	—		—		47.7

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	For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Renewable Energy	$	160.6	$	89.9	$	70.3	$	63.2	$	89.8	$	65.5	$	51.0	$	123.7	$	60.8
Purchased Power and Capacity	50.4		5.1		6.6		49.4		4.4		18.2		81.0		4.0		18.9
Peaker CfDs	13.0		—		—		20.9		—		—		38.7		—		—
Transmission Support Commitments	8.6		8.6		4.6		9.2		9.2		5.0		7.8		7.8		4.2
Coal, Wood and Other (1)	—		—		—		—		—		—		—		—		47.7

⁽¹⁾ PSNH previously entered into various arrangements for the purchase of coal, wood and the transportation services for fuel supply for its electric generating assets. In 2018, Eversource and PSNH completed the sales of PSNH's thermal and hydroelectric generation assets. Upon sale, the remaining future contractual obligations were transferred to the respective buyers. See Note 14, "Generation Asset Sale," for further information.

C.     Spent Nuclear Fuel Obligations - Yankee Companies

CL&P, NSTAR Electric and PSNH have plant closure and fuel storage cost obligations to the Yankee Companies, which have each completed the physical decommissioning of their respective nuclear power facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies fund these costs through litigation proceeds received from the DOE and, to the extent necessary, through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. CL&P, NSTAR Electric and PSNH, in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies collect amounts that management believes are adequate to recover the remaining plant closure and fuel storage cost estimates for the respective plants. Management believes CL&P and NSTAR Electric will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers.

Spent Nuclear Fuel Litigation:

The Yankee Companies have filed complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to accept delivery of, and provide for a permanent facility to store, spent nuclear fuel pursuant to the terms of the 1983 spent fuel and high-level waste disposal contracts between the Yankee Companies and the DOE. The court previously awarded the Yankee Companies damages for Phases I, II and III of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2012, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.

DOE Phase IV Damages - On May 22, 2017, each of the Yankee Companies filed a fourth set of lawsuits against the DOE in the Court of Federal

Claims. The Yankee Companies sought monetary damages totaling $104.4 million for CYAPC, YAEC and MYAPC, resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2013 to 2016 (“DOE Phase IV”). On February 21, 2019, the Yankee Companies received a partial summary judgment and partial final judgment in their favor for the undisputed amount of monetary damages of $103.2 million.  The court awarded CYAPC, YAEC, and MYAPC damages of $40.7 million, $28.1 million and $34.4 million, respectively. The DOE did not appeal the court's judgment and the decision became final on April 23, 2019. On June 12, 2019, each of the Yankee Companies received the damages proceeds. On June 12, 2019, the court accepted an offer of judgment in the amount of $0.5 million to settle the disputed amount of approximately $1 million in Phase IV contested damages. The Yankee Companies received the $0.5 million payment in July 2019. CYAPC's and YAEC's proceeds received were classified as operating activities on the Eversource consolidated statement of cash flows.

In September 2019, the Yankee Companies made a required informational filing with FERC as to the use of proceeds, for which approval was received in the fourth quarter of 2019. In December 2019, YAEC and MYAPC returned proceeds of $5.4 million and $21.0 million, respectively, to its member companies, of which the Eversource utilities (CL&P, NSTAR Electric and PSNH) received a total of $2.8 million from YAEC and $5.0 million from MYAPC. The Eversource utilities will ultimately refund these proceeds to utility customers. Also, in December 2019, CYAPC paid $29.0 million to the DOE to partially settle its pre-1983 spent nuclear fuel obligation.

D.    Guarantees and Indemnifications

In the normal course of business, Eversource parent provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric and PSNH, in the form of guarantees. Management does not anticipate a material impact to net income or cash flows as a result of these various guarantees and indemnifications.  The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries and affiliates to external parties as of December 31, 2019:

Company	Description	Maximum Exposure (in millions)		Expiration Dates
Various	Surety Bonds (1)	$	29.2	2020 - 2021
Rocky River Realty Company and Eversource Service	Lease Payments for Real Estate	6.5		2024
Bay State Wind LLC	Real Estate Purchase	2.5		2020
Sunrise Wind LLC	Offshore Wind (2)	2.2		—

⁽¹⁾  Surety bond expiration dates reflect termination dates, the majority of which will be renewed or extended.  Certain surety bonds contain credit ratings triggers that would require Eversource parent to post collateral in the event that the unsecured debt credit ratings of Eversource parent are downgraded.  

⁽²⁾  On October 25, 2019, Eversource parent issued a guaranty on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guaranty Sunrise Wind LLC's performance of certain obligations, in an amount not to exceed $15.4 million, under the Offshore Wind Renewable Energy Certificate Purchase and Sale Agreement (the Agreement). The Agreement was executed on October 25, 2019, by and between NYSERDA and Sunrise Wind LLC. Obligations of Eversource parent under the guaranty expire at such time as the guaranteed obligations have been fully performed. The Company regularly reviews performance risk under this arrangement, and in the event it becomes probable that Eversource parent will be required to perform under the guarantee, the amount of probable payment will be recorded. As of December 31, 2019, the fair value of the guarantee was immaterial.

Eversource parent issued a guaranty on behalf of its subsidiary, NPT, under which, beginning at the time the Northern Pass Transmission line would go into commercial operation, Eversource parent would guarantee the financial obligations of NPT under the TSA with HQ in an amount not to exceed $25 million.  Eversource parent's obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations. In the second quarter of 2019, Eversource concluded that construction of the NPT project was no longer probable. For further information regarding the impairment of NPT, see Note 1D, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements. While this guaranty is currently outstanding, it is expected to be extinguished in connection with the final dissolution of NPT.

E.    FERC ROE Complaints

Four separate complaints were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively, the Complainants). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive (incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, the FERC set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the Court).

All amounts associated with the first complaint period have been refunded, which totaled $38.9 million (pre-tax and excluding interest) at Eversource and reflected both the base ROE and incentive cap prescribed by the FERC order. The refund consisted of $22.4 million for CL&P, $13.7 million for NSTAR Electric and $2.8 million for PSNH.

Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of December 31, 2019. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of December 31, 2019.

On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.

The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.

If the results of the illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order.

On November 21, 2019, FERC issued an order concerning the transmission ROEs for the Midcontinent ISO transmission owners (MISO). In that order, FERC adopted another new methodology for determining base ROEs for MISO, which differed significantly from the methodology and framework set forth in its October 16, 2018 FERC order on the NETOs’ ROE dockets. On December 23, 2019, the NETOs filed a Supplemental Paper Hearing Brief and a Motion to supplement the record in the NETO ROE dockets to respond to the new methodology proposed in the MISO order, as there is uncertainty to whether it may be applied to the NETOs’ cases. On January 21, 2020, the FERC issued an order granting rehearing for further consideration to give the FERC more time to act on the substantive issues of the MISO ROE proceedings. Further changes to the methodology by FERC are possible as a result of the arguments in both the MISO and NETO proceedings. Given the significant uncertainty relating to the October 2018 FERC order, the November 2019 FERC order to MISO, and the FERC's rehearing of the MISO order, the Company is unable to predict the potential effect of the MISO order on the NETO complaints or the outcome of the four complaints and concluded that there is

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no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods at this time. Further, the Company cannot reasonably estimate a range of gain or loss for any of the four complaint proceedings.

Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.

A change of 10 basis points to the base ROE used to establish the reserves would impact Eversource’s after-tax earnings by an average of approximately $3 million for each of the four 15-month complaint periods.

F.    Eversource and NSTAR Electric Boston Harbor Civil Action

On July 15, 2016, the United States Attorney on behalf of the United States Army Corps of Engineers filed a civil action in the United States District Court for the District of Massachusetts under provisions of the Rivers and Harbors Act of 1899 and the Clean Water Act against NSTAR Electric, HEEC, and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the Defendants).  The action alleged that the Defendants failed to comply with certain permitting requirements related to the placement of the HEEC-owned electric distribution cable beneath Boston Harbor.  The action sought an order to compel HEEC to comply with cable depth requirements in the United States Army Corps of Engineers' permit or alternatively to remove the electric distribution cable and cease unauthorized work in U.S. waterways.  The action also sought civil penalties and other costs.

The parties reached a settlement pursuant to which HEEC agreed to install a new 115kV distribution cable across Boston Harbor to Deer Island, utilizing a different route, and remove portions of the existing cable. Upon the installation and completion of the new cable and the removal of the portions of the existing cable, all issues surrounding the current permit from the United States Army Corps of Engineers are expected to be resolved, and such litigation is expected to be dismissed with prejudice. Construction of the new distribution cable was completed in August 2019 and removal of the portions of the existing cable was completed in January 2020.

NSTAR Electric agreed to provide a rate base credit of $17.5 million to the Massachusetts Water Resources Authority for the new cable. This negotiated credit resulted in the initial $17.5 million of construction costs on the new cable being expensed as incurred, all of which was fully expensed in 2018. In connection with the new cable that was placed into service, a corresponding ARO was recognized for approximately $32 million within Other Long-Term Liabilities on the Eversource and NSTAR Electric balance sheets as of December 31, 2019.  For further information on the ARO, see Note 7, "Asset Retirement Obligations," to the financial statements.

G.     Litigation and Legal Proceedings

Eversource, including CL&P, NSTAR Electric and PSNH, are involved in legal, tax and regulatory proceedings regarding matters arising in the ordinary course of business, which involve management's assessment to determine the probability of whether a loss will occur and, if probable, its best estimate of probable loss.  The Company records and discloses losses when these losses are probable and reasonably estimable, and discloses matters when losses are probable but not estimable or when losses are reasonably possible.  Legal costs related to the defense of loss contingencies are expensed as incurred.

14.    GENERATION ASSET SALE

On January 10, 2018, PSNH completed the sale of its thermal generation assets. The original purchase price of $175 million was adjusted to reflect working capital adjustments, closing date adjustments and proration of taxes and fees prior to closing. As a result of these adjustments, net proceeds from the sale of the thermal assets totaled $116.8 million. On August 26, 2018, PSNH completed the sale of its hydroelectric generation assets. The original purchase price of $83 million was adjusted to reflect contractual adjustments totaling $5.8 million, resulting in net proceeds of $77.2 million. The difference between the carrying value of the hydroelectric generation assets and the sale proceeds resulted in a gain of $17.3 million. An estimated gain from the sale of these assets was included as an offset to the total remaining costs associated with the sale of generation assets that were securitized on May 8, 2018.

On May 8, 2018, PSNH Funding issued $635.7 million of securitized RRBs to finance PSNH's unrecovered remaining costs resulting from the divestiture of its generation assets, which included the deferred costs resulting from the sale of the thermal generation assets. These RRBs are secured by a non-bypassable charge recoverable from PSNH customers. PSNH recorded regulatory assets and other deferred costs in connection with the generation asset divestiture and the securitization of remaining costs, which are probable of recovery through collection of the non-bypassable charge. As of December 31, 2019 and 2018, unamortized securitized stranded costs totaled $565.3 million and $608.4 million, respectively, and are included in Regulatory Assets on the Eversource and PSNH balance sheets. For further information on the securitized RRB issuance, see Note 10, "Rate Reduction Bonds and Variable Interest Entities."

On November 27, 2019, PSNH filed a motion for the commencement of audit of divestiture-related costs. PSNH’s actual balance of costs eligible for recovery as divestiture-related costs is $654.0 million, which is above the $635.7 million amount securitized in May 2018. PSNH proposed to recover this balance through the SCRC tracker mechanism and believes the amount deferred is probable of recovery. These deferred costs are recorded in Other Long-Term Assets on the balance sheet.

For the year ended December 31, 2018, pre-tax income associated with the hydroelectric assets prior to the sale on August 26, 2018 was $9.9 million. For the year ended December 31, 2017, pre-tax income associated with PSNH's generation assets was $60.0 million. As of December 31, 2018, all generation assets had been sold.

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15.     LEASES

Eversource, including CL&P, NSTAR Electric and PSNH, has entered into lease agreements as a lessee for the use of land, office space, service centers, vehicles, information technology, and equipment. These lease agreements are classified as either finance or operating leases and the liability and right-of-use asset are recognized on the balance sheet at lease commencement.  Leases with an initial term of 12 months or less are not recorded on the balance sheet and are recognized as lease expense on a straight-line basis over the lease term.

Eversource determines whether or not a contract contains a lease based on whether or not it provides Eversource with the use of a specifically identified asset for a period of time, as well as both the right to direct the use of that asset and receive the significant economic benefits of the asset. Eversource has elected the practical expedient to not separate non-lease components from lease components and instead to account for both as a single lease component, with the exception of the information technology asset class where the lease and non-lease components are separated.

The provisions of Eversource, CL&P, NSTAR Electric and PSNH lease agreements contain renewal options. The renewal options range from one year to twenty years. The renewal period is included in the measurement of the lease liability if it is reasonably certain that Eversource will exercise these renewal options.

For leases entered into or modified after the January 1, 2019 implementation date, the discount rate utilized for classification and measurement purposes as of the inception date of the lease is based on each company's collateralized incremental interest rate to borrow over a comparable term for an individual lease because the rate implicit in the lease is not determinable.

CL&P and PSNH entered into certain contracts for the purchase of energy that qualify as leases.  These contracts do not have minimum lease payments and therefore are not recognized as a lease liability on the balance sheet and are not reflected in the future minimum lease payments table below.  Expense related to these contracts is included as variable lease cost in the table below. The expense and long-term obligation for these contracts are also included in Note 13B, "Commitments and Contingencies - Long-Term Contractual Arrangements," to the financial statements.  

The components of lease cost, prior to amounts capitalized, are as follows:

	For the Year Ended December 31, 2019
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
Financing Lease Cost:
Amortization of Right-of-use-Assets	$	1.7	$	0.7	$	0.2	$	0.1
Interest on Lease Liabilities	1.2		0.6		0.6		—
Total Finance Lease Cost	2.9		1.3		0.8		0.1
Operating Lease Cost	11.7		0.5		3.4		0.1
Variable Lease Cost	60.5		13.3		—		47.2
Total Lease Cost	$	75.1	$	15.1	$	4.2	$	47.4

Operating lease rental payments charged to expense in 2018 and 2017 (which exclude CL&P's and PSNH's energy purchase contracts) were as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2018	$	10.8	$	10.9	$	11.8	$	2.5
2017	10.5		11.7		11.3		3.3

Operating lease cost, net of the capitalized portion, is included in Operations and Maintenance (or Purchased Power, Fuel and Transmission expense for transmission segment leases) on the statements of income. Amortization of finance lease assets is included in Depreciation on the statements of income. Interest expense on finance leases is included in Interest Expense on the statements of income.

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Supplemental balance sheet information related to leases is as follows:

		As of December 31, 2019
(Millions of Dollars)	Balance Sheet Classification	Eversource		CL&P		NSTAR Electric		PSNH
Operating Leases:
Operating Lease Right-of-use-Assets, Net	Other Long-Term Assets	$	49.9	$	0.7	$	24.2	$	0.4
Operating Lease Liabilities
Operating Lease Liabilities - Current Portion	Other Current Liabilities	$	8.6	$	0.5	$	0.7	$	0.1
Operating Lease Liabilities - Long-Term	Other Long-Term Liabilities	41.3		0.2		23.5		0.3
Total Operating Lease Liabilities		$	49.9	$	0.7	$	24.2	$	0.4
Finance Leases:
Finance Lease Right-of-use-Assets, Net	Property, Plant and Equipment, Net	$	8.2	$	1.9	$	3.3	$	0.9
Finance Lease Liabilities
Finance Lease Liabilities - Current Portion	Other Current Liabilities	$	2.4	$	1.6	$	—	$	0.1
Finance Lease Liabilities - Long-Term	Other Long-Term Liabilities	8.1		1.4		4.4		0.8
Total Finance Lease Liabilities		$	10.5	$	3.0	$	4.4	$	0.9

The finance lease payments that NSTAR Electric will make over the next twelve months are entirely interest-related, due to escalating payments. As such, none of the finance lease payments over the next twelve months will reduce the finance lease liability.

Other information related to leases is as follows (in millions of dollars, unless otherwise noted):

	Eversource		CL&P		NSTAR Electric		PSNH
As of December 31, 2019
Weighted-Average Remaining Lease Term (Years):
Operating Leases	12		2		20		9
Finance Leases	12		2		22		9
Weighted-Average Discount Rate (Percentage):
Operating Leases	3.9	%	2.5	%	4.1	%	3.7	%
Finance Leases	4.0	%	10.5	%	2.9	%	3.5	%

	Eversource		CL&P		NSTAR Electric		PSNH
For the Year Ended December 31, 2019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$	11.4	$	0.4	$	1.6	$	0.1
Operating Cash Flows from Finance Leases	1.2		0.6		0.6		—
Financing Cash Flows from Finance Leases	2.6		1.4		—		0.1
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	2.9		1.0		0.1		0.2
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	2.0		—		—		—

Future minimum lease payments, excluding variable costs, under long-term leases, as of December 31, 2019 are as follows:

	Operating Leases								Finance Leases
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Year Ending December 31,
2020	$	10.2	$	0.5	$	1.8	$	0.1	$	3.4	$	2.0	$	0.6	$	0.1
2021	9.0		0.2		1.6		0.1		2.9		1.5		0.6		0.1
2022	7.4		—		1.6		0.1		1.5		—		0.6		0.1
2023	4.9		—		1.6		—		0.8		—		0.6		0.1
2024	2.8		—		1.7		—		0.8		—		0.7		0.1
Thereafter	28.9		0.1		28.7		0.2		13.1		—		12.6		0.5
Future lease payments	63.2		0.8		37.0		0.5		22.5		3.5		15.7		1.0
Less amount representing interest	13.3		0.1		12.8		0.1		12.0		0.5		11.3		0.1
Present value of future minimum lease payments	$	49.9	$	0.7	$	24.2	$	0.4	$	10.5	$	3.0	$	4.4	$	0.9

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At December 31, 2018, future minimum rental payments, excluding executory costs, such as property taxes, state use taxes, insurance, and maintenance were as follows:

Operating Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	11.5	$	1.5	$	7.2	$	0.5
2020	9.8		1.4		6.0		0.4
2021	8.7		1.2		5.3		0.4
2022	7.2		1.1		4.4		0.4
2023	4.7		0.5		3.1		0.2
Thereafter	32.7		0.2		29.5		0.3
Future minimum lease payments	$	74.6	$	5.9	$	55.5	$	2.2

Capital Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	3.4	$	2.0	$	0.5	$	0.1
2020	3.4		2.0		0.5		0.1
2021	2.9		1.5		0.5		0.1
2022	1.5		—		0.6		0.1
2023	0.7		—		0.6		0.1
Thereafter	13.9		—		13.4		0.5
Future minimum lease payments	25.8		5.5		16.1		1.0
Less amount representing interest	13.8		1.0		12.4		0.1
Present value of future minimum lease payments	$	12.0	$	4.5	$	3.7	$	0.9

16.     FAIR VALUE OF FINANCIAL INSTRUMENTS

The following methods and assumptions were used to estimate the fair value of each of the following financial instruments:

Preferred Stock, Long-Term Debt and Rate Reduction Bonds:  The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections.  The fair value of long-term debt and RRB debt securities is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields.  The fair values provided in the table below are classified as Level 2 within the fair value hierarchy.  Carrying amounts and estimated fair values are as follows:

	Eversource				CL&P				NSTAR Electric				PSNH
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
As of December 31, 2019:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	162.0	$	116.2	$	117.8	$	43.0	$	44.2	$	—	$	—
Long-Term Debt	14,098.2		15,170.2		3,518.1		4,058.0		3,342.1		3,659.9		951.6		1,005.7
Rate Reduction Bonds	583.3		625.9		—		—		—		—		583.3		625.9
As of December 31, 2018:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	156.8	$	116.2	$	113.8	$	43.0	$	43.0	$	—	$	—
Long-Term Debt	13,086.1		13,154.9		3,254.0		3,429.2		2,944.8		3,024.1		805.2		819.5
Rate Reduction Bonds	635.7		645.8		—		—		—		—		635.7		645.8

Derivative Instruments and Marketable Securities: Derivative instruments and investments in marketable securities are carried at fair value.  For further information, see Note 4, "Derivative Instruments," and Note 5, "Marketable Securities," to the financial statements.  

See Note 1I, "Summary of Significant Accounting Policies – Fair Value Measurements," for the fair value measurement policy and the fair value hierarchy.

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17.     ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

The changes in accumulated other comprehensive income/(loss) by component, net of tax, are as follows:

	For the Year Ended December 31, 2019												For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Qualified Cash Flow Hedging Instruments			Unrealized Gains/(Losses) on Marketable Securities			Defined Benefit Plans			Total			Qualified Cash Flow Hedging Instruments			Unrealized Losses on Marketable Securities			Defined Benefit Plans			Total
Balance as of January 1st	$	(4.4	)	$	(0.5	)	$	(55.1	)	$	(60.0	)	$	(6.2	)	$	—		$	(60.2	)	$	(66.4	)
OCI Before Reclassifications	—			1.2			(13.3		)	(12.1		)	—			(0.5		)	0.3			(0.2		)
Amounts Reclassified from AOCI	1.4			—			5.6			7.0			1.8			—			4.8			6.6
Net OCI	1.4			1.2			(7.7		)	(5.1		)	1.8			(0.5		)	5.1			6.4
Balance as of December 31st	$	(3.0	)	$	0.7		$	(62.8	)	$	(65.1	)	$	(4.4	)	$	(0.5	)	$	(55.1	)	$	(60.0	)

Eversource's qualified cash flow hedging instruments represent interest rate swap agreements on debt issuances that were settled in prior years. The settlement amount was recorded in AOCI and is being amortized into Net Income over the term of the underlying debt instrument.  CL&P, NSTAR Electric and PSNH continue to amortize interest rate swaps settled in prior years from AOCI into Interest Expense over the remaining life of the associated long-term debt. Such interest rate swaps are not material to their respective financial statements.

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses that arose during the year and were recognized in AOCI. The unamortized actuarial gains and losses and prior service costs on the defined benefit plans are amortized from AOCI into Other Income, Net over the average future employee service period, and are reflected in amounts reclassified from AOCI. The related tax effects recognized in AOCI were net deferred tax assets of $4.4 million and $4.1 million in 2019 and 2017, respectively, and deferred tax liabilities of $0.2 million in 2018.

Eversource did not elect to reclassify the income tax effects of the Tax Cuts and Jobs Act from AOCI to Retained Earnings as permitted by ASU 2018-02, Income Statement – Reporting Comprehensive Income (Topic 220).

The following table sets forth the amounts reclassified from AOCI by component and the impacted line item on the statements of income:

	Amounts Reclassified from AOCI
Eversource (Millions of Dollars)	For the Years Ended December 31,									Statements of Income Line Item Impacted
	2019			2018			2017
Qualified Cash Flow Hedging Instruments	$	(2.5	)	$	(2.8	)	$	(3.3	)	Interest Expense
Tax Effect	1.1			1.0			1.3			Income Tax Expense
Qualified Cash Flow Hedging Instruments, Net of Tax	$	(1.4	)	$	(1.8	)	$	(2.0	)
Defined Benefit Plan Costs:
Amortization of Actuarial Losses	$	(5.7	)	$	(6.0	)	$	(6.2	)	Other Income, Net (1)
Amortization of Prior Service Cost	(1.8		)	(0.4		)	(1.1		)	Other Income, Net (1)
Total Defined Benefit Plan Costs	(7.5		)	(6.4		)	(7.3		)
Tax Effect	1.9			1.6			2.8			Income Tax Expense
Defined Benefit Plan Costs, Net of Tax	$	(5.6	)	$	(4.8	)	$	(4.5	)
Total Amounts Reclassified from AOCI, Net of Tax	$	(7.0	)	$	(6.6	)	$	(6.5	)

⁽¹⁾  These amounts are included in the computation of net periodic Pension, SERP and PBOP costs.  See Note 1M, "Summary of Significant Accounting Policies – Other Income, Net" and Note 11A, "Employee Benefits – Pension Benefits and Postretirement Benefits Other Than Pension," for further information.

As of December 31, 2019, it is estimated that a pre-tax amount of $2.5 million ($0.7 million for NSTAR Electric and $1.8 million for PSNH) will be reclassified from AOCI as a decrease to Net Income over the next 12 months as a result of the amortization of the interest rate swap agreements which have been settled.  In addition, it is estimated that a pre-tax amount of $7.8 million will be reclassified from AOCI as a decrease to Net Income over the next 12 months as a result of the amortization of Pension, SERP and PBOP costs.

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18.     DIVIDEND RESTRICTIONS

Eversource parent's ability to pay dividends may be affected by certain state statutes, the ability of its subsidiaries to pay common dividends and the leverage restriction tied to its consolidated total debt to total capitalization ratio requirement in its revolving credit agreement.  Pursuant to the joint revolving credit agreement of Eversource, CL&P, PSNH, NSTAR Gas, Yankee Gas and Aquarion Water Company of Connecticut, and to the NSTAR Electric revolving credit agreement, each company is required to maintain consolidated total indebtedness to total capitalization ratio of no greater than 65 percent at the end of each fiscal quarter. As of December 31, 2019, all companies were in compliance with such covenant and in compliance with all such provisions of the revolving credit agreements that may restrict the payment of dividends as of December 31, 2019.

The Retained Earnings balances subject to dividend restrictions were $4.2 billion for Eversource, $1.8 billion for CL&P, $2.3 billion for NSTAR Electric and $490.3 million for PSNH as of December 31, 2019.

CL&P, NSTAR Electric and PSNH are subject to Section 305 of the Federal Power Act that makes it unlawful for a public utility to make or pay a dividend from any funds "properly included in its capital account." Management believes that this Federal Power Act restriction, as applied to CL&P, NSTAR Electric and PSNH, would not be construed or applied by the FERC to prohibit the payment of dividends from retained earnings for lawful and legitimate business purposes. In addition, certain state statutes may impose additional limitations on such companies and on NSTAR Gas, Yankee Gas, Aquarion Water Company of Connecticut, Aquarion Water Company of Massachusetts and Aquarion Water Company of New Hampshire. Such state law restrictions do not restrict the payment of dividends from retained earnings or net income.

19.     COMMON SHARES

The following table sets forth the Eversource parent common shares and the shares of common stock of CL&P, NSTAR Electric and PSNH that were authorized and issued, as well as the respective per share par values:  

	Shares
	Par Value		Authorized as of December 31, 2019 and 2018	Issued as of December 31,
				2019	2018
Eversource	$	5	380,000,000	345,858,402	333,878,402
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

Common Share Issuance and Forward Sale Agreement: On June 4, 2019, Eversource completed an equity offering of 17,940,000 common shares, consisting of 5,980,000 common shares issued directly by the Company and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resulted in proceeds of $426.9 million, net of issuance costs.

Under the forward sale agreement, a total of 11,960,000 common shares were borrowed from third parties and sold by the underwriters. The forward sale agreement allows Eversource, at its election and prior to May 29, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially, $71.48 per share) or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as dividends.

On December 30, 2019, Eversource physically settled a portion of the forward sale agreement by delivering 6,000,000 common shares in exchange for net proceeds of $425.4 million. The forward sale price used to determine the cash proceeds received by Eversource was calculated based on the initial forward sale price of $71.48 per share, as adjusted in accordance with the forward sale agreement.

The 2019 issuances of 11,980,000 common shares resulted in proceeds of $852.3 million, net of issuance costs, and were reflected in shareholders’ equity and as financing activities on the statement of cash flows.

Eversource’s intent is to physically settle the forward sale agreement by issuing common shares. As of December 31, 2019, if Eversource had elected to net settle the forward sale agreement, Eversource would have been required to pay $84.4 million under a cash settlement or would have been required to deliver 992,189 common shares under a net share settlement.

Issuances of shares under the forward sale agreement are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreement have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method. See Note 22, "Earnings Per Share," to the financial statements for information on the forward sale agreement’s impact on the calculation of diluted EPS.

Eversource used the net proceeds received upon the direct issuance of common shares and the net proceeds received upon partial settlement of the forward sale agreement to repay short-term debt under the commercial paper program, to fund capital spending and clean energy initiatives, and for general corporate purposes.

Treasury Shares: As of December 31, 2019 and 2018, there were 15,977,757 and 16,992,594 Eversource common shares held as treasury shares, respectively.  As of December 31, 2019 and 2018, there were 329,880,645 and 316,885,808 Eversource common shares outstanding, respectively.

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Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan.

20.     PREFERRED STOCK NOT SUBJECT TO MANDATORY REDEMPTION

The CL&P and NSTAR Electric preferred stock is not subject to mandatory redemption and is presented as a noncontrolling interest of a subsidiary in Eversource's financial statements.

CL&P is authorized to issue up to 9,000,000 shares of preferred stock, par value $50 per share, and NSTAR Electric is authorized to issue 2,890,000 shares of preferred stock, par value $100 per share. Holders of preferred stock of CL&P and NSTAR Electric are entitled to receive cumulative dividends in preference to any payment of dividends on the common stock. Upon liquidation, holders of preferred stock of CL&P and NSTAR Electric are entitled to receive a liquidation preference before any distribution to holders of common stock in an amount equal to the par value of the preferred stock plus accrued and unpaid dividends. If the net assets were to be insufficient to pay the liquidation preference in full, then the net assets would be distributed ratably to all holders of preferred stock. The preferred stock of CL&P and NSTAR Electric is subject to optional redemption by the CL&P and NSTAR Electric Boards of Directors at any time.

Details of preferred stock not subject to mandatory redemption are as follows (in millions, except in redemption price and shares):

		Redemption Price Per Share		Shares Outstanding as of December 31,		As of December 31,
Series				2019	2018	2019			2018
CL&P
$1.90	Series of 1947	$	52.50	163,912	163,912	$	8.2		$	8.2
$2.00	Series of 1947	$	54.00	336,088	336,088	16.8			16.8
$2.04	Series of 1949	$	52.00	100,000	100,000	5.0			5.0
$2.20	Series of 1949	$	52.50	200,000	200,000	10.0			10.0
3.90%	Series of 1949	$	50.50	160,000	160,000	8.0			8.0
$2.06	Series E of 1954	$	51.00	200,000	200,000	10.0			10.0
$2.09	Series F of 1955	$	51.00	100,000	100,000	5.0			5.0
4.50%	Series of 1956	$	50.75	104,000	104,000	5.2			5.2
4.96%	Series of 1958	$	50.50	100,000	100,000	5.0			5.0
4.50%	Series of 1963	$	50.50	160,000	160,000	8.0			8.0
5.28%	Series of 1967	$	51.43	200,000	200,000	10.0			10.0
$3.24	Series G of 1968	$	51.84	300,000	300,000	15.0			15.0
6.56%	Series of 1968	$	51.44	200,000	200,000	10.0			10.0
Total CL&P				2,324,000	2,324,000	$	116.2		$	116.2
NSTAR Electric
4.25%	Series of 1956	$	103.625	180,000	180,000	$	18.0		$	18.0
4.78%	Series of 1958	$	102.80	250,000	250,000	25.0			25.0
Total NSTAR Electric				430,000	430,000	$	43.0		$	43.0
Fair Value Adjustment due to Merger with NSTAR						(3.6		)	(3.6		)
Other
6.00%	Series of 1958	$	100.00	23	23	$	—		$	—
Total Eversource - Noncontrolling Interest - Preferred Stock of Subsidiaries						$	155.6		$	155.6

21.     COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $7.5 million for each of the years ended December 31, 2019, 2018 and 2017.  These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of December 31, 2019 and 2018.  On the Eversource balance sheets, Common Shareholders' Equity was fully attributable to Eversource parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.

For the years ended December 31, 2019, 2018 and 2017, there was no change in ownership of the common equity of CL&P and NSTAR Electric.  

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22.     EARNINGS PER SHARE

Basic EPS is computed based upon the weighted average number of common shares outstanding during each period.  Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards and the equity forward sale agreement, as if they were converted into outstanding common shares.  The dilutive effect of unvested RSU and performance share awards, as well as the equity forward sale agreement, is calculated using the treasury stock method.  RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied.  

As described in Note 19, "Common Shares," earnings per share dilution, if any, related to the forward sale agreement will be determined under the treasury stock method until settlement of the forward sale agreement. Under this method, the number of Eversource common shares used in calculating diluted EPS is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreement less the number of shares that would be purchased by Eversource in the market (based on the average market price during the same reporting period) using the proceeds receivable upon settlement (based on the adjusted forward sale price at the end of that reporting period). Share dilution occurs when the average market price of Eversource's common shares is higher than the adjusted forward sale price.

The following table sets forth the components of basic and diluted EPS:

Eversource (Millions of Dollars, except share information)	For the Years Ended December 31,
	2019		2018		2017
Net Income Attributable to Common Shareholders	$	909.1	$	1,033.0	$	988.0
Weighted Average Common Shares Outstanding:
Basic	321,416,086		317,370,369		317,411,097
Dilutive Effect of:
Share-Based Compensation Awards and Other	762,215		623,565		620,483
Equity Forward Sale Agreement	763,335		—		—
Total Dilutive Effect	1,525,550		623,565		620,483
Diluted	322,941,636		317,993,934		318,031,580
Basic EPS	$	2.83	$	3.25	$	3.11
Diluted EPS	$	2.81	$	3.25	$	3.11

23.    REVENUES

On January 1, 2018, Eversource, including CL&P, NSTAR Electric and PSNH, adopted ASU 2014-09, “Revenue from Contracts with Customers (Topic 606)” using the modified retrospective approach. The core principle of this accounting guidance is that revenue is recognized when promised goods or services (referred to as performance obligations) are transferred to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. A five-step model is used for recognizing and measuring revenue from contracts with customers, which includes identifying the contract with the customer, identifying the performance obligations promised within the contract, determining the transaction price (the amount of consideration to which the company expects to be entitled), allocating the transaction price to the performance obligations and recognizing revenue when (or as) the performance obligation is satisfied.

The following table presents operating revenues disaggregated by revenue source:

	For the Year Ended December 31, 2019
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution			Electric Transmission		Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	3,723.7	$	555.1		$	—	$	132.3		$	—	$	—		$	4,411.1
Commercial	2,584.8		347.6			—		63.9			—		(4.3		)	2,992.0
Industrial	331.8		96.9			—		4.5			—		(11.6		)	421.6
Total Retail Tariff Sales Revenues	6,640.3		999.6			—		200.7			—		(15.9		)	7,824.7
Wholesale Transmission Revenues	—		—			1,293.3		—			61.3		(1,085.2		)	269.4
Wholesale Market Sales Revenues	215.7		55.4			—		4.1			—		—			275.2
Other Revenues from Contracts with Customers	54.8		2.8			13.2		7.0			967.2		(969.0		)	76.0
Reserve for Revenues Subject to Refund	1.3		6.2			—		(2.8		)	—		—			4.7
Total Revenues from Contracts with Customers	6,912.1		1,064.0			1,306.5		209.0			1,028.5		(2,070.1		)	8,450.0
Alternative Revenue Programs	45.9		(4.9		)	81.8		4.6			—		(74.2		)	53.2
Other Revenues	18.5		3.1			0.7		1.0			—		—			23.3
Total Operating Revenues	$	6,976.5	$	1,062.2		$	1,389.0	$	214.6		$	1,028.5	$	(2,144.3	)	$	8,526.5

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	For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	3,766.6		$	542.5		$	—		$	130.7		$	—	$	—		$	4,439.8
Commercial	2,634.7			334.8			—			63.3			—		(4.5		)	3,028.3
Industrial	351.9			96.0			—			4.4			—		(10.0		)	442.3
Total Retail Tariff Sales Revenues	6,753.2			973.3			—			198.4			—		(14.5		)	7,910.4
Wholesale Transmission Revenues	—			—			1,308.9			—			47.3		(1,092.2		)	264.0
Wholesale Market Sales Revenues	179.5			57.5			—			4.1			—		—			241.1
Other Revenues from Contracts with Customers	65.9			(2.2		)	12.6			7.2			889.0		(891.0		)	81.5
Reserve for Revenues Subject to Refund	(12.3		)	(8.3		)	—			(3.7		)	—		—			(24.3		)
Total Revenues from Contracts with Customers	6,986.3			1,020.3			1,321.5			206.0			936.3		(1,997.7		)	8,472.7
Alternative Revenue Programs	(47.0		)	(1.2		)	(35.2		)	5.4			—		31.9			(46.1		)
Other Revenues	17.9			3.1			—			0.6			—		—			21.6
Total Operating Revenues	$	6,957.2		$	1,022.2		$	1,286.3		$	212.0		$	936.3	$	(1,965.8	)	$	8,448.2

	For the Years Ended December 31,
	2019									2018
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	1,837.1		$	1,322.1		$	564.5		$	1,828.2		$	1,380.9		$	557.5
Commercial	922.9			1,349.4			314.6			928.1			1,391.5			316.9
Industrial	138.3			115.8			77.7			147.7			124.9			79.3
Total Retail Tariff Sales Revenues	2,898.3			2,787.3			956.8			2,904.0			2,897.3			953.7
Wholesale Transmission Revenues	587.1			517.3			188.9			620.6			488.8			199.5
Wholesale Market Sales Revenues	105.1			73.1			37.5			48.3			76.1			56.6
Other Revenues from Contracts with Customers	36.4			18.7			15.6			35.0			28.9			15.5
Reserve for Revenues Subject to Refund	—			—			1.3			—			—			(12.3		)
Total Revenues from Contracts with Customers	3,626.9			3,396.4			1,200.1			3,607.9			3,491.1			1,213.0
Alternative Revenue Programs	77.5			41.6			8.6			(65.9		)	0.9			(17.3		)
Other Revenues	10.3			7.0			1.9			8.5			8.3			1.1
Eliminations	(482.1		)	(400.4		)	(144.7		)	(454.3		)	(387.4		)	(149.2		)
Total Operating Revenues	$	3,232.6		$	3,044.6		$	1,065.9		$	3,096.2		$	3,112.9		$	1,047.6

Retail Tariff Sales: Regulated utilities provide products and services to their regulated customers under rates, pricing, payment terms and conditions of service, regulated by each state regulatory agency. The arrangement whereby a utility provides commodity service to a customer for a price approved by the respective state regulatory commission is referred to as a tariff sale contract, and the tariff governs all aspects of the provision of regulated services by utilities. The majority of revenue for Eversource, CL&P, NSTAR Electric and PSNH is derived from regulated retail tariff sales for the sale and distribution of electricity, natural gas and water to residential, commercial and industrial retail customers.

The utility's performance obligation for the regulated tariff sales is to provide electricity, natural gas or water to the customer as demanded. The promise to provide the commodity represents a single performance obligation, as it is a promise to transfer a series of distinct goods or services that are substantially the same and that have the same pattern of transfer to the customer. Revenue is recognized over time as the customer simultaneously receives and consumes the benefits provided by the utility, and the utility satisfies its performance obligation. Revenue is recognized based on the output method as there is a directly observable output to the customer (electricity, natural gas or water units delivered to the customer and immediately consumed). Each Eversource utility is entitled to be compensated for performance completed to date (service taken by the customer) until service is terminated.

In regulated tariff sales, the transaction prices are the rates approved by the respective state regulatory commissions.  In general, rates can only be changed through formal proceedings with the state regulatory commissions. These rates are designed to recover the costs to provide service to customers and include a return on investment. Regulatory commission-approved tracking mechanisms are included in these rates and are also used to recover, on a fully-reconciling basis, certain costs, such as the procurement of energy supply, retail transmission charges, energy efficiency program costs, net metering for distributed generation, and restructuring and stranded costs. These tracking mechanisms result in rates being changed periodically to ensure recovery of actual costs incurred.

Customers may elect to purchase electricity from each Eversource electric utility or may contract separately with a competitive third party supplier. Revenue is not recorded for the sale of the electricity commodity to customers who have contracted separately with these suppliers, only the delivery to a customer, as the utility is acting as an agent on behalf of the third party supplier.

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Wholesale Transmission Revenues:  The Eversource electric transmission-owning companies (CL&P, NSTAR Electric and PSNH) each own and maintain transmission facilities that are part of an interstate power transmission grid over which electricity is transmitted throughout New England. CL&P, NSTAR Electric and PSNH, as well as most other New England utilities, are parties to a series of agreements that provide for coordinated planning and operation of the region's transmission facilities and the rules by which they acquire transmission services.  The Eversource electric transmission-owning companies have a combination of FERC-approved regional and local formula rates that work in tandem to recover all their transmission costs. These rates are part of the ISO-NE Tariff. Regional rates recover the costs of higher voltage transmission facilities that benefit the region and are collected from all New England transmission customers, including the Eversource distribution businesses. Eversource's local rates recover the companies' total transmission revenue requirements, less revenues received from regional rates and other sources, and are collected from Eversource's distribution businesses and other transmission customers. The distribution businesses of Eversource, in turn, recover the FERC approved charges from retail customers through annual or semiannual tracking mechanisms, which are retail tariff sales.

The utility's performance obligation for regulated wholesale transmission sales is to provide transmission services to the customer as demanded. The promise to provide transmission service represents a single performance obligation. The transaction prices are the transmission rate formulas as defined by the ISO-NE Tariff and are regulated and established by FERC. Wholesale transmission revenue is recognized over time as the performance obligation is completed, which occurs as transmission services are provided to customers. The revenue is recognized based on the output method. Each Eversource utility is entitled to be compensated for performance completed to date (e.g., use of the transmission system by the customer).

Wholesale Market Sales Revenues: Wholesale market sales transactions include sales of energy and energy-related products into the ISO-NE wholesale electricity market, sales of natural gas to third party marketers, and also the sale of RECs to various counterparties. ISO-NE oversees the region's wholesale electricity market and administers the transactions and terms and conditions, including payment terms, which are established in the ISO-NE tariff, between the buyers and sellers in the market. Pricing is set by the wholesale market. The wholesale transactions in the ISO-NE market occur on a day-ahead basis or a real-time basis (daily) and are, therefore, short-term. Transactions are tracked and reported by ISO-NE net by the hour, which is the net hourly position of energy sales and purchases by each market participant. Beginning in the first quarter of 2018, the performance obligation for ISO-NE energy transactions is defined to be the net by hour transaction. Revenue is recognized when the performance obligation for these energy sales transactions is satisfied, when the sale occurs and the energy is transferred to the customer. For sales of natural gas, transportation, and natural gas pipeline capacity to third party marketers, revenue is recognized when the performance obligation is satisfied at the point in time the sale occurs and the natural gas or related product is transferred to the marketer. RECs are sold to various counterparties, and revenue is recognized when the performance obligation is satisfied upon transfer of title to the customer through the New England Power Pool Generation Information System.

Other Revenues from Contracts with Customers: Other revenues from contracts with customers primarily include property rentals that are not deemed leases. These revenues are generally recognized on a straight-line basis over time as the service is provided to the customer. Other revenues also include revenues from Eversource's service company, which is eliminated in consolidation.

Reserve for Revenues Subject to Refund: Current base rates include an estimate of income taxes, which was based on the U.S. federal corporate income tax rate in effect at the time of the rate proceeding. Eversource established a regulatory liability, recorded as a reduction to revenue, to reflect the difference between the 35 percent federal corporate income tax rate included in rates charged to customers and the 21 percent federal corporate income tax rate, effective January 1, 2018 as a result of the Tax Cuts and Jobs Act, until rates billed to customers reflect the lower federal tax rate. Effective May 1, 2018, CL&P adjusted distribution rates billed to customers to reflect the lower federal income tax rate prospectively and, as of December 31, 2018, fully refunded its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through April 30, 2018. Effective November 15, 2018, Yankee Gas adjusted distribution rates to reflect the lower federal income tax rate prospectively and to refund its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through November 14, 2018. Effective July 1, 2019, PSNH adjusted temporary distribution rates to reflect the lower federal income tax rate prospectively and to refund its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through June 30, 2019. For NSTAR Electric and NSTAR Gas, a December 2018 DPU order indicated that the DPU would not require a revision to base distribution rates for any potential refunds associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 to the effective dates of each company's rate changes (effective February 1, 2018 for NSTAR Electric and July 1, 2018 for NSTAR Gas).

Alternative Revenue Programs: In accordance with accounting guidance for rate-regulated operations, certain of Eversource's utilities' rate making mechanisms qualify as alternative revenue programs (ARPs) if they meet specified criteria, in which case revenues may be recognized prior to billing based on allowed levels of collection in rates. Eversource's utility companies recognize revenue and record a regulatory asset or liability once the condition or event allowing for the automatic adjustment of future rates occurs. ARP revenues include both the recognition of the deferral adjustment to ARP revenues, when the regulator-specified condition or event allowing for additional billing or refund has occurred, and an equal and offsetting reversal of the ARP deferral to revenues as those amounts are reflected in the price of service in subsequent periods.

Eversource’s ARPs include the revenue decoupling mechanism and the annual reconciliation adjustment to transmission formula rates, described below.

• Certain Eversource electric, natural gas and water companies, including CL&P and NSTAR Electric, have revenue decoupling mechanisms approved by a regulatory commission (decoupled companies). Decoupled companies’ distribution revenues are not directly based on sales volumes. The decoupled companies reconcile their annual base distribution rate recovery to pre-established levels of baseline distribution delivery service revenues, with any difference between the allowed level of distribution revenue and the actual amount realized adjusted through subsequent rates.

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• The transmission formula rates provide for the annual reconciliation and recovery or refund of estimated costs to actual costs.  The financial impacts of differences between actual and estimated costs are deferred for future recovery from, or refund to, transmission customers.  This transmission deferral reconciles billed transmission revenues to the revenue requirement for our transmission businesses.

Other Revenues: Other Revenues include certain fees charged to customers that are not considered revenue from contracts with customers and lease revenues under lessor accounting guidance. Lease revenues totaled $4.4 million at Eversource, $1.0 million at CL&P, and $2.7 million at NSTAR Electric for the year ended December 31, 2019.

Intercompany Eliminations: Intercompany eliminations are primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business, and revenues from Eversource's service company. Intercompany revenues and expenses between the Eversource wholesale transmission businesses and the Eversource distribution businesses and from Eversource's service company are eliminated in consolidation and included in "Eliminations" in the table above.

Receivables: Receivables, Net on the balance sheet include trade receivables from our retail customers and receivables arising from ISO-NE billing related to wholesale transmission contracts and wholesale market transactions, sales of natural gas and capacity to marketers, sales of RECs, and property rentals. In general, retail tariff customers and wholesale transmission customers are billed monthly and the payment terms are generally due and payable upon receipt of the bill.

Unbilled Revenues: Unbilled Revenues on the balance sheet represent estimated amounts due from retail customers for electricity, natural gas or water delivered to customers but not yet billed. The utility company has satisfied its performance obligation and the customer has received and consumed the commodity as of the balance sheet date, and therefore, the utility company records revenue for those services in the period the services were provided. Only the passage of time is required before the company is entitled to payment for the satisfaction of the performance obligation. Payment from customers is due monthly as services are rendered and amounts are billed. Actual amounts billed to customers when meter readings become available may vary from the estimated amount.

Unbilled revenues are recognized by allocating estimated unbilled sales volumes to the respective customer classes, and then applying an estimated rate by customer class to those sales volumes. Unbilled revenue estimates reflect seasonality, weather, customer usage patterns, customer rates in effect for customer classes, and the timing of customer billing. The companies that have a decoupling mechanism record a regulatory deferral to reflect the actual allowed amount of revenue associated with their respective decoupled distribution rate design.

Practical Expedients: Eversource has elected practical expedients in the accounting guidance that allow the company to record revenue in the amount that the company has a right to invoice, if that amount corresponds directly with the value to the customer of the company's performance to date, and not to disclose related unsatisfied performance obligations. Retail and wholesale transmission tariff sales fall into this category, as these sales are recognized as revenue in the period the utility provides the service and completes the performance obligation, which is the same as the monthly amount billed to customers. There are no other material revenue streams for which Eversource has unsatisfied performance obligations.

24.     SEGMENT INFORMATION

Eversource is organized into the Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reportable segments and Other based on a combination of factors, including the characteristics of each segments' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates.  These reportable segments represent substantially all of Eversource's total consolidated revenues.  Revenues from the sale of electricity, natural gas and water primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer.  The Electric Distribution reportable segment includes the results of PSNH's generation facilities prior to sales in January and August 2018, and NSTAR Electric's solar power facilities. On December 4, 2017, Eversource acquired Aquarion, and its water distribution business was deemed a reportable segment beginning in 2018. Eversource's reportable segments are determined based upon the level at which Eversource's chief operating decision maker assesses performance and makes decisions about the allocation of company resources.  

The remainder of Eversource's operations is presented as Other in the tables below and primarily consists of 1) the equity in earnings of Eversource parent from its subsidiaries and intercompany interest income, both of which are eliminated in consolidation, and interest expense related to the debt of Eversource parent, 2) the revenues and expenses of Eversource Service, most of which are eliminated in consolidation, 3) the operations of CYAPC and YAEC, 4) Eversource Water Ventures, Inc., parent company of Aquarion, 5) the results of other unregulated subsidiaries, which are not part of its core business, and 6) Eversource parent's equity ownership interests that are not consolidated, which primarily include the offshore wind business, a natural gas pipeline owned by Enbridge, Inc., and a renewable energy investment fund.

In the ordinary course of business, Yankee Gas and NSTAR Gas purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline project described above. These affiliate transaction costs total $62.5 million annually and are classified as Purchased Power, Fuel and Transmission on the Eversource statements of income.

Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has one reportable segment.  

Cash flows used for investments in plant included in the segment information below are cash capital expenditures that do not include amounts incurred but not paid, cost of removal, AFUDC related to equity funds, and the capitalized portions of pension and PBOP expense.

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Eversource's segment information is as follows:

	For the Year Ended December 31, 2019
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues	$	6,976.5		$	1,062.2		$	1,389.0		$	214.6		$	1,028.5		$	(2,144.3	)	$	8,526.5
Depreciation and Amortization	(651.3		)	(68.3		)	(253.3		)	(46.9		)	(63.2		)	2.3			(1,080.7		)
Impairment of Northern Pass Transmission	—			—			(239.6		)	—			—			—			(239.6		)
Other Operating Expenses	(5,525.1		)	(830.8		)	(411.2		)	(101.0		)	(891.3		)	2,143.7			(5,615.7		)
Operating Income	800.1			163.1			484.9			66.7			74.0			1.7			1,590.5
Interest Expense	(206.4		)	(47.4		)	(125.7		)	(34.6		)	(170.3		)	51.2			(533.2		)
Interest Income	13.3			0.1			1.5			—			48.7			(50.8		)	12.8
Other Income, Net	46.8			1.6			29.2			0.4			1,041.5			(999.5		)	120.0
Income Tax (Expense)/Benefit	(135.9		)	(21.2		)	(130.5		)	2.4			11.7			—			(273.5		)
Net Income	517.9			96.2			259.4			34.9			1,005.6			(997.4		)	916.6
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income Attributable to Common Shareholders	$	513.3		$	96.2		$	256.5		$	34.9		$	1,005.6		$	(997.4	)	$	909.1
Total Assets (as of)	$	22,541.9		$	4,345.5		$	10,904.0		$	2,351.7		$	20,469.6		$	(19,488.8	)	$	41,123.9
Cash Flows Used for Investments in Plant	$	1,104.2		$	460.2		$	987.0		$	118.0		$	242.1		$	—		$	2,911.5

	For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues (1)	$	6,957.2		$	1,022.2		$	1,286.3		$	212.0		$	936.3		$	(1,965.8	)	$	8,448.2
Depreciation and Amortization	(671.8		)	(75.0		)	(231.8		)	(46.5		)	(49.1		)	2.2			(1,072.0		)
Other Operating Expenses (1)	(5,548.6		)	(787.6		)	(375.5		)	(99.8		)	(831.5		)	1,966.7			(5,676.3		)
Operating Income	736.8			159.6			679.0			65.7			55.7			3.1			1,699.9
Interest Expense	(202.8		)	(44.1		)	(120.6		)	(34.3		)	(129.3		)	32.3			(498.8		)
Interest Income	18.7			—			2.4			—			30.3			(33.3		)	18.1
Other Income/(Loss), Net	67.5			7.1			31.1			(0.4		)	1,185.3			(1,180.3		)	110.3
Income Tax (Expense)/Benefit	(160.2		)	(29.4		)	(161.8		)	(0.1		)	62.5			—			(289.0		)
Net Income	460.0			93.2			430.1			30.9			1,204.5			(1,178.2		)	1,040.5
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income Attributable to Common Shareholders	$	455.4		$	93.2		$	427.2		$	30.9		$	1,204.5		$	(1,178.2	)	$	1,033.0
Total Assets (as of)	$	21,389.1		$	3,904.9		$	10,285.0		$	2,253.0		$	17,874.2		$	(17,464.9	)	$	38,241.3
Cash Flows Used for Investments in Plant (2)	$	961.3		$	351.5		$	976.2		$	102.3		$	178.6		$	—		$	2,569.9

	For the Year Ended December 31, 2017
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues (1)	$	5,542.9		$	947.3		$	1,301.7		$	15.9		$	931.0		$	(986.8	)	$	7,752.0
Depreciation and Amortization	(542.6		)	(72.9		)	(209.4		)	(3.7		)	(37.4		)	2.2			(863.8		)
Other Operating Expenses (1)	(4,072.6		)	(716.4		)	(382.8		)	(8.3		)	(806.6		)	986.7			(5,000.0		)
Operating Income	927.7			158.0			709.5			3.9			87.0			2.1			1,888.2
Interest Expense	(186.3		)	(43.1		)	(115.1		)	(3.1		)	(90.0		)	15.8			(421.8		)
Interest Income	7.3			0.1			1.8			0.1			15.7			(16.7		)	8.3
Other Income, Net	41.6			3.8			27.3			—			1,113.0			(1,086.0		)	99.7
Income Tax Expense	(288.3		)	(44.2		)	(228.7		)	(2.1		)	(15.5		)	(0.1		)	(578.9		)
Net Income/(Loss)	502.0			74.6			394.8			(1.2		)	1,110.2			(1,084.9		)	995.5
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income/(Loss) Attributable to Common Shareholders	$	497.4		$	74.6		$	391.9		$	(1.2	)	$	1,110.2		$	(1,084.9	)	$	988.0
Cash Flows Used for Investments in Plant	$	1,020.7		$	298.2		$	867.6		$	16.0		$	145.6		$	—		$	2,348.1

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⁽¹⁾ Effective January 1, 2018, upon implementation of the new revenue accounting guidance, the electric distribution segment is presented gross and intercompany transmission billings are presented in the eliminations column, as Eversource believes that the electric distribution segment acts as a principal, rather than an agent, in its contracts with retail customers. Retail customers contract directly with the electric distribution utility and do not differentiate between distribution and transmission services. Therefore, the electric distribution segment revenues, which are derived from retail customer billings, are presented gross of the eliminations. Prior to 2018, the electric distribution segment presented intercompany electric transmission billings net, based on indicators of net presentation prior to the new revenue guidance.  See Note 23 "Revenues," to the financial statements regarding accounting for revenues.

⁽²⁾ See Note 1B, "Summary of Significant Accounting Policies - Basis of Presentation," for information regarding the correction of cash investments in plant reported in 2018.

25.     ACQUISITION OF AQUARION AND GOODWILL

A.    Acquisition of Aquarion

On December 4, 2017, Eversource acquired Aquarion for a purchase price of $1.675 billion, consisting of approximately $880 million in cash and $795 million of assumed Aquarion debt. Aquarion is a holding company that owns three separate regulated water utility subsidiaries engaged in the water collection, treatment and distribution business that operate in Connecticut, Massachusetts and New Hampshire. These regulated utilities collect, treat and distribute water to residential, commercial and industrial customers, to other utilities for resale, and for private and municipal fire protection. Aquarion and its subsidiaries became wholly-owned subsidiaries of Eversource, and Eversource's consolidated financial information includes Aquarion and its subsidiaries' activity beginning December 4, 2017. The approximate $880 million cash purchase price included the $745 million equity purchase price plus a $135 million shareholder loan that was repaid at closing.

Pro Forma Financial Information: The following unaudited pro forma financial information reflects the pro forma combined results of operations of Eversource and Aquarion and reflects the amortization of purchase price adjustments assuming the acquisition had taken place on January 1, 2017. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of Eversource.

(Pro forma amounts in millions, except share amounts)	For the Year Ended December 31, 2017
Operating Revenues	$	7,947.7
Net Income Attributable to Common Shareholders	1,019.1
Basic EPS	3.21
Diluted EPS	3.20

Aquarion Revenues and Pre-Tax Income: The impact of Aquarion on Eversource's accompanying consolidated statement of income included operating revenues of $15.9 million and pre-tax income of $1.1 million for the year ended December 31, 2017.

B.    Goodwill

In a business combination, the excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed

is recognized as goodwill. Goodwill is evaluated for impairment at least annually and more frequently if indicators of impairment arise. In accordance with the accounting standards, if the fair value of a reporting unit is less than its carrying value (including goodwill), the goodwill is tested for impairment. Goodwill is not subject to amortization, however is subject to a fair value based assessment for impairment at least annually and whenever facts or circumstances indicate that there may be an impairment.  A resulting write-down, if any, would be charged to Operating Expenses.   

Eversource's reporting units for the purpose of testing goodwill are Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution. These reporting units are consistent with the operating segments underlying the reportable segments identified in Note 24, "Segment Information," to the financial statements.

Eversource completed its annual goodwill impairment test for Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reporting units as of October 1, 2019 and determined that no impairment existed. There were no events subsequent to October 1, 2019 that indicated impairment of goodwill. The annual goodwill assessment included an evaluation of the Company's share price and credit ratings, analyst reports, financial performance, cost and risk factors, long-term strategy, growth and future projections, as well as macroeconomic, industry and market conditions.  This evaluation required the consideration of several factors that impact the fair value of the reporting units, including conditions and assumptions that affect the future cash flows of the reporting units. Key considerations include discount rates, utility sector market performance and merger transaction multiples, and internal estimates of future cash flows and net income.  

 The following table presents goodwill by reportable segment as of December 31, 2019 and 2018:

(Billions of Dollars)	Electric Distribution		Electric Transmission		Natural Gas Distribution		Water Distribution		Total
Goodwill	$	2.5	$	0.6	$	0.4	$	0.9	$	4.4

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26.     QUARTERLY FINANCIAL DATA (UNAUDITED)

	Quarter Ended
Eversource (Millions of Dollars, except   per share information)	2019								2018
	March 31,		June 30, (2)		September 30,		December 31,		March 31,		June 30,		September 30,		December 31,
Operating Revenues	$	2,415.8	$	1,884.5	$	2,175.8	$	2,050.4	$	2,288.0	$	1,853.9	$	2,271.4	$	2,034.9
Operating Income	494.7		151.0		509.2		435.6		442.5		391.4		466.0		400.0
Net Income	310.6		33.3		320.8		251.9		271.4		244.6		291.3		233.2
Net Income Attributable   to Common Shareholders	308.7		31.5		318.9		250.0		269.5		242.8		289.4		231.3
Basic EPS (1)	$	0.97	$	0.10	$	0.98	$	0.77	$	0.85	$	0.76	$	0.91	$	0.73
Diluted EPS (1)	$	0.97	$	0.10	$	0.98	$	0.76	$	0.85	$	0.76	$	0.91	$	0.73

⁽¹⁾    The summation of quarterly EPS data may not equal annual data due to rounding.

⁽²⁾  In the second quarter of 2019, Eversource recorded an impairment charge related to NPT of $239.6 million within Operating Income on the statement of income. For further information, see Note 1D, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements.

	Quarter Ended
	2019								2018
(Millions of Dollars)	March 31,		June 30,		September 30,		December 31,		March 31,		June 30,		September 30,		December 31,
CL&P
Operating Revenues	$	849.2	$	740.8	$	853.9	$	788.7	$	785.0	$	694.9	$	865.0	$	751.3
Operating Income	171.8		166.8		190.3		152.7		157.2		163.1		172.7		142.8
Net Income	110.5		104.8		111.7		83.9		98.6		99.7		100.3		79.1
NSTAR Electric
Operating Revenues	$	797.6	$	681.9	$	878.7	$	686.4	$	770.1	$	690.7	$	939.5	$	712.6
Operating Income	137.8		134.2		219.4		135.5		119.0		133.6		205.5		126.0
Net Income	94.0		89.7		154.9		93.4		77.1		87.9		140.6		77.5
PSNH
Operating Revenues	$	276.4	$	240.9	$	280.4	$	268.2	$	267.4	$	235.1	$	290.2	$	254.9
Operating Income	49.7		46.3		64.5		56.0		55.8		46.9		56.5		37.2
Net Income	32.8		26.9		40.9		33.4		35.1		25.8		40.7		14.3

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Item 9.    Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

No events that would be described in response to this item have occurred with respect to Eversource, CL&P, NSTAR Electric or PSNH.

Item 9A.    Controls and Procedures

Management, on behalf of Eversource, CL&P, NSTAR Electric and PSNH, is responsible for the preparation, integrity, and fair presentation of the accompanying Financial Statements and other sections of this combined Annual Report on Form 10-K.  Eversource's internal controls over financial reporting were audited by Deloitte & Touche LLP.    

Management, on behalf of Eversource, CL&P, NSTAR Electric and PSNH, is responsible for establishing and maintaining adequate internal controls over financial reporting.  The internal control framework and processes have been designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP.  There are inherent limitations of internal controls over financial reporting that could allow material misstatements due to error or fraud to occur and not be prevented or detected on a timely basis by employees during the normal course of business.  Additionally, internal controls over financial reporting may become inadequate in the future due to changes in the business environment.  Under the supervision and with the participation of the principal executive officer and principal financial officer, an evaluation of the effectiveness of internal controls over financial reporting was conducted based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).  Based on this evaluation under the framework in COSO, management concluded that internal controls over financial reporting at Eversource, CL&P, NSTAR Electric and PSNH were effective as of December 31, 2019.

Management, on behalf of Eversource, CL&P, NSTAR Electric and PSNH, evaluated the design and operation of the disclosure controls and procedures as of December 31, 2019 to determine whether they are effective in ensuring that the disclosure of required information is made timely and in accordance with the Securities Exchange Act of 1934 and the rules and regulations of the SEC.  This evaluation was made under management's supervision and with management's participation, including the principal executive officer and principal financial officer as of the end of the period covered by this Annual Report on Form 10-K.  There are inherent limitations of disclosure controls and procedures, including the possibility of human error and the circumventing or overriding of the controls and procedures.  Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives.  The principal executive officer and principal financial officer have concluded, based on their review, that the disclosure controls and procedures of Eversource, CL&P, NSTAR Electric and PSNH are effective to ensure that information required to be disclosed by us in reports filed under the Securities Exchange Act of 1934 (i) is recorded, processed, summarized, and reported within the time periods specified in SEC rules and regulations and (ii) is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosures.

There have been no changes in internal controls over financial reporting for Eversource, CL&P, NSTAR Electric and PSNH during the quarter ended December 31, 2019 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.

Item 9B.    Other Information

No information is required to be disclosed under this item as of December 31, 2019, as this information has been previously disclosed in applicable reports on Form 8-K during the fourth quarter of 2019.

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PART III

Item 10.    Directors, Executive Officers and Corporate Governance

The information in Item 10 is provided as of February 26, 2020, except where otherwise indicated.

Certain information required by this Item 10 is omitted for NSTAR Electric and PSNH pursuant to Instruction I(2)(c) to Form 10-K, Omission of Information by Certain Wholly Owned Subsidiaries.

Eversource Energy

In addition to the information provided below concerning the executive officers of Eversource Energy, incorporated herein by reference is the information to be contained in the sections captioned “Election of Trustees,” “Governance of Eversource Energy” and the related subsections, “Selection of Trustees,” and “Delinquent Section 16(a) Reports” of Eversource Energy’s definitive proxy statement for solicitation of proxies, expected to be filed with the SEC on or about March 26, 2020.

Eversource Energy and CL&P

Each member of CL&P’s Board of Directors is an employee of Eversource Service.  Directors are elected annually to serve for one year until their successors are elected and qualified. CL&P is a wholly owned subsidiary of Eversource Energy.

Set forth below is certain information concerning CL&P’s directors as well as Eversource Energy’s and CL&P’s executive officers:

Name	Age	Title
James J. Judge	64	Chairman of the Board, President and Chief Executive Officer and a Trustee of Eversource Energy; Chairman and director of CL&P
Philip J. Lembo	64	Executive Vice President and Chief Financial Officer of Eversource Energy and CL&P; director of CL&P
Gregory B. Butler	62	Executive Vice President and General Counsel of Eversource Energy and CL&P; director of CL&P
Christine M. Carmody 1	57	Executive Vice President-Human Resources and Information Technology of Eversource Energy
Joseph R. Nolan, Jr. 1	56	Executive Vice President-Strategy, Customer and Corporate Relations of Eversource Energy
Werner J. Schweiger	60	Executive Vice President and Chief Operating Officer of Eversource Energy; Chief Executive Officer and director of CL&P
Jay S. Buth	50	Vice President, Controller and Chief Accounting Officer of Eversource Energy and CL&P

¹ Deemed an executive officer of CL&P pursuant to Rule 3b-7 under the Securities Exchange Act of 1934.

James J. Judge.  Mr. Judge has served as Chairman of the Board, President and Chief Executive Officer of Eversource Energy since May 3, 2017. Previously, Mr. Judge served as President and Chief Executive Officer, and a Trustee, of Eversource Energy from May 4, 2016 until May 3, 2017, and as Executive Vice President and Chief Financial Officer of Eversource Energy from April 10, 2012 until May 4, 2016. Mr. Judge has served as Chairman of CL&P since May 4, 2016, and as a director of CL&P since April 10, 2012. Based on his experience described above, Mr. Judge has the skills and qualifications necessary to serve as a director of CL&P.

Philip J. Lembo. Mr. Lembo has served as Chief Financial Officer of Eversource Energy and CL&P since May 4, 2016. He previously served as Treasurer of Eversource Energy from April 10, 2012 until May 3, 2017, and as Treasurer of CL&P from April 10, 2012 until March 31, 2017. Mr. Lembo has served as Executive Vice President of Eversource Energy and CL&P since August 8, 2016. Previously, he served as Senior Vice President of Eversource Energy and CL&P from May 4, 2016 until August 8, 2016, and as Vice President of Eversource Energy and CL&P from April 10, 2012 until May 4, 2016. Mr. Lembo has served as a director of CL&P since May 4, 2016. Based on his experience described above, Mr. Lembo has the skills and qualifications necessary to serve as a director of CL&P.

Gregory B. Butler.  Mr. Butler has served as General Counsel of Eversource Energy since May 1, 2001, and of CL&P since March 9, 2006. He has served as Executive Vice President of Eversource Energy and CL&P since August 8, 2016. Previously, Mr. Butler served as Senior Vice President of Eversource Energy from December 1, 2005 to August 8, 2016, and of CL&P from March 9, 2006 until August 8, 2016. He has served as a director of CL&P since April 22, 2009. Based on his experience described above, Mr. Butler has the skills and qualifications necessary to serve as a director of CL&P.

Christine M. Carmody.  Ms. Carmody has served as Executive Vice President-Human Resources and Information Technology of Eversource Energy since August 8, 2016. Previously Ms. Carmody served as Senior Vice President-Human Resources of Eversource Energy from May 4, 2016 until August 8, 2016; and of Eversource Service from April 10, 2012 until August 8, 2016.

124

Joseph R. Nolan, Jr.  Mr. Nolan has served as Executive Vice President-Strategy, Customer and Corporate Relations of Eversource Energy since February 5, 2020. Previously Mr. Nolan served as Executive Vice President-Customer and Corporate Relations of Eversource Energy from August 8, 2016 to February 5, 2020. He served as Senior Vice President-Corporate Relations of Eversource Energy from May 4, 2016 until August 8, 2016, and of Eversource Service from April 10, 2012 until August 8, 2016.

Werner J. Schweiger.  Mr. Schweiger has served as Executive Vice President and Chief Operating Officer of Eversource Energy since September 2, 2014, and as Chief Executive Officer of CL&P since August 11, 2014. Mr. Schweiger has served as a director of CL&P since May 28, 2013.  He previously served as President of CL&P from June 2, 2015 until June 27, 2016. Based on his experience described above, Mr. Schweiger has the skills and qualifications necessary to serve as a director of CL&P.

Jay S. Buth.  Mr. Buth has served as Vice President, Controller and Chief Accounting Officer of Eversource Energy and CL&P since April 10, 2012.

There are no family relationships between any director or executive officer and any other trustee, director or executive officer of Eversource Energy or CL&P and none of the above executive officers or directors serves as an executive officer or director pursuant to any agreement or understanding with any other person.  Our executive officers hold the offices set forth opposite their names until the next annual meeting of the Board of Trustees, in the case of Eversource Energy, and the Board of Directors, in the case of CL&P, and until their successors have been elected and qualified.

CL&P obtains audit services from the independent registered public accounting firm engaged by the Audit Committee of Eversource Energy’s Board of Trustees.  CL&P does not have its own audit committee or, accordingly, an audit committee financial expert.  CL&P relies on Eversource Energy’s audit committee and the audit committee financial expert.

CODE OF ETHICS AND CODE OF BUSINESS CONDUCT

Each of Eversource Energy, CL&P, NSTAR Electric, and PSNH has adopted a Code of Ethics for Senior Financial Officers (Chief Executive Officer, Chief Financial Officer and Controller) and the Code of Business Conduct, which are applicable to all Trustees, directors, officers, employees, contractors and agents of Eversource Energy, CL&P, NSTAR Electric and PSNH.  The Code of Ethics and the Code of Business Conduct have both been posted on the Eversource Energy web site and are available at www.eversource.com/Content/general/about/investors/corporate-governance on the Internet.  Any amendments to or waivers from the Code of Ethics and Code of Business Conduct for executive officers, directors or Trustees will be posted on the website.  Any such amendment or waiver would require the prior consent of the Board of Trustees or an applicable committee thereof.

Printed copies of the Code of Ethics and the Code of Business Conduct are also available to any shareholder without charge upon written request mailed to:

Richard J. Morrison

Secretary

Eversource Energy

800 Boylston Street, 17th Floor

Boston, Massachusetts 02199-7050

Item 11. Executive Compensation

Eversource Energy

The information required by this Item 11 for Eversource Energy is incorporated herein by reference to certain information contained in Eversource Energy's definitive proxy statement for solicitation of proxies, which is expected to be filed with the SEC on or about March 26, 2020, under the sections captioned "Compensation Discussion and Analysis," plus related subsections, and "Compensation Committee Report," plus related subsections following such Report.

NSTAR ELECTRIC and PSNH

Certain information required by this Item 11 has been omitted for NSTAR Electric and PSNH pursuant to Instruction I(2)(c) to Form 10-K, Omission of Information by Certain Wholly-Owned Subsidiaries.

CL&P

The information in this Item 11 relates solely to CL&P.

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COMPENSATION DISCUSSION AND ANALYSIS

CL&P is a wholly-owned subsidiary of Eversource Energy.  Its board of directors consists entirely of executive officers of Eversource Energy system companies.  CL&P does not have a compensation committee, and the Compensation Committee of Eversource Energy's Board of Trustees determines compensation for the executive officers of CL&P, including their salaries, annual incentive awards and long-term incentive awards.  All of CL&P's "Named Executive Officers," as defined below, also serve as officers of Eversource Energy and one or more other subsidiaries of Eversource Energy.  Compensation set by the Compensation Committee of Eversource Energy (the Committee) and set forth herein is for services rendered to Eversource Energy and its subsidiaries by such officers in all capacities.

This Compensation Discussion and Analysis (CD&A) provides information about the principles behind Eversource Energy's compensation objectives, plans, policies and actions for the Named Executive Officers. The discussion describes the specific components of Eversource Energy's compensation programs and approach to executive compensation, how Eversource Energy measures performance, and how Eversource Energy's compensation principles were applied to compensation awards and decisions that were made by the Compensation Committee for the Named Executive Officers, as presented in the tables and narratives that follow. While this discussion focuses primarily on 2019 information, it also addresses decisions that were made in prior periods to the extent that these decisions are relevant to the full understanding of Eversource Energy's compensation programs and the decisions that were made regarding 2019 performance. The CD&A also contains an assessment of performance measured against the established 2019 goals and additional accomplishments, the compensation awards made by the Compensation Committee, and other information relating to Eversource Energy's compensation programs, including:

=	Summary of 2019 Accomplishments	=	2019 Annual Incentive Program
=	Pay for Performance Philosophy	=	Performance Goal Assessment Matrix
=	Executive Compensation Governance	=	Long-Term Incentive Program
=	Named Executive Officers	=	Clawback and No Hedging and No Pledging Policies
=	Overview of the Compensation Program	=	Share Ownership Guidelines
=	Market Analysis	=	Other Benefits
=	Mix of Compensation Elements	=	Contractual Agreements
=	Results of 2019 Say on Pay	=	Tax and Accounting Considerations
=	Elements of 2019 Compensation	=	Equity Grant Practices
=	Risk Analysis of Executive Compensation	=	Compensation Committee Report

Summary of 2019 Accomplishments

2019 was an exceptionally successful year, and in many respects, the most successful year in Eversource Energy's history. Eversource achieved Total Shareholder Return of 34.4 percent, had its best system reliability performance ever, and established Eversource as a clean energy and ESG industry leader. Eversource's performance was outstanding in each area that is important to its shareholders, customers, employees and communities. The following is a summary of some of Eversource's most important accomplishments in 2019:

2019 Financial Accomplishments

• FINANCIAL PERFORMANCE: Eversource's 2019 earnings per share equaled $2.81 per share, and non-GAAP earnings per share equaled $3.45, which excludes an impairment charge of $0.64 per share relating to the Northern Pass Transmission Project.¹ 

¹ Non-GAAP EPS presented in this CD&A excludes the impairment charge for the Northern Pass Transmission Project (NPT) of $0.64 per share. Eversource Energy uses this non-GAAP financial measure to more fully compare and explain 2019 results without including the impact of the NPT impairment charge. Management believes the NPT impairment charge is not indicative of Eversource Energy's ongoing performance. Due to the nature and significance of the impairment charge on net income attributable to common shareholders, management believes that the non-GAAP presentation is a more meaningful representation of Eversource Energy's financial performance and provides additional information to readers in analyzing historical and future performance of the business. Non-GAAP financial measures should not be considered as alternatives to Eversource Energy's consolidated net income attributable to common shareholders.

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• DIVIDENDS PAID: Eversource's Board of Trustees increased the annual dividend rate by 5.9 percent for 2019 to $2.14 per share, which exceeded the EEI index of companies' median dividend growth rate of 5.1 percent. The dividend growth rate for the period 2017 - 2019 has averaged 6.3 percent, exceeding the utility industry average.

    

• SHAREHOLDER RETURN: Eversource's Total Shareholder Return in 2019 was 34.4 percent, compared to the 25.8 percent total shareholder return of the EEI Index and a 31.5 percent total shareholder return for the Standard & Poor's 500. Eversource outperformed the EEI Index and the Standard & Poor's 500 over the last one-, three-, five- and 10-year periods. An investment of $1,000 in Eversource common shares for the ten-year period beginning January 1, 2010 was worth $4,567 on December 31, 2019. The following chart represents the comparative one-, three- five- and 10-year total shareholder returns for the periods ended December 31, 2019, respectively:

• STOCK PRICE: Eversource's stock price rose from $65.04 on January 1, 2019 to $85.07 on December 31, 2019, a gain of 30.8 percent, outperforming its peers.

• CLEAN ENERGY: Eversource has strengthened its prospects through new clean energy projects. Eversource continued to expand its offshore wind partnership with Ørsted, the global leader of offshore wind development, through the acquisition of the Northeast U.S. assets of Deepwater Wind. The partnership successfully bid into the New York clean energy request for proposals and was awarded a contract for 880 megawatts of offshore wind with the Sunrise Wind project, and advanced the New London State Pier agreement to support offshore wind construction. The partnership is recognized as the leading developer of offshore wind in North America. Eversource accelerated the original five-year electric vehicle charging program in Massachusetts to three years, and the program met its 2019 targets. Also, Eversource commenced the construction process on two energy storage projects in Massachusetts, and in addition, Eversource's energy efficiency programs continue to be recognized as being best in the nation by the American Council for an Energy Efficient Economy.

• CREDIT RATING: Eversource holds an A- Corporate Credit Rating at Standard & Poor's. There is no other utility with a higher credit rating in the EEI Index.

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2019 Operational Accomplishments

• RELIABILITY PERFORMANCE: Electric System Reliability, measured by months between interruptions, was top decile for Eversource's industry and its best year ever. Eversource's overall electric system reliability performance in 2019 improved by 26 percent; customer power interruptions were on average 21.6 months apart.

    

• RESTORATION PERFORMANCE: The average system outage duration was 59.2 minutes, a 23 percent improvement over 2018, also top decile and Eversource's best year ever.

    

• SAFETY: Eversource's safety performance of 0.7, measured by days away, restricted or transferred (DART) per 100 workers, has improved significantly since 2016 and continued to outperform the industry in 2019.

    

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• REGULATORY: Eversource achieved very constructive regulatory outcomes, including an approximate $28 million temporary rate settlement approval at PSNH, successful recovery approval of Eversource's storm costs in the three states that it serves, and a negotiated settlement with the Federal Energy Regulatory Commission to align rate structure and create additional customer rate transparency.

• CUSTOMER: Eversource continued to advance its transformation of the customer experience with a new mobile application, improved accuracy of restoration time estimates, and further increases in customer digital engagement.

2019 Environmental, Social and Governance Accomplishments

• SUSTAINABILITY: Eversource's performance was ranked top decile within a peer group of comparably sized (market capitalization) U.S. utilities whose ESG performance is assessed by the two leading sustainability rating firms; this exceeded Eversource's goal of 75th percentile performance. Eversource also announced its new, industry leading but attainable goal, to be the only U.S. investor owned energy utility to be carbon neutral by 2030.

• COMMUNITY: Eversource continued to make a significant impact in its communities through its corporate philanthropy programs and extensive employee community volunteer programs. Eversource employees have more than doubled the hours they have devoted to volunteerism in the communities, from 15,000 hours in 2016 to over 37,000 hours in 2019.

• DIVERSITY: In 2019, 41 percent of Eversource's new hires and promotions into leadership roles were women or people of color, exceeding the goal of 40 percent.

• EMPLOYEES: Eversource advanced Diversity & Inclusion through continued leadership commitment and Active Diversity Councils and Business Resource Groups. Eversource was recognized for its commitment to advancing women in the workplace, having been selected for the 2019 Bloomberg Gender-Equality Index. Eversource's 2019 Employee Pulse Survey reported significantly higher engagement by employees; survey scores continue to improve, increasing by 11 percent over the 2018 survey and 22 percent over the 2016 results.

• AWARDS: Eversource received numerous local and national awards recognizing it as a leader and catalyst in the areas of Sustainability and ESG, including:

• In November 2019, Forbes magazine/JUST Capital ranked Eversource as the #1 energy and utilities company. The listing recognizes corporate responsibility and commitment to the local communities and celebrates public companies for their positive impact and leadership on priorities such as ethical leadership, environmental impact, customer treatment, fair pay and benefits, equal opportunity and shareholder return.

• Newsweek magazine's Most Responsible Companies' review ranked Eversource the #1 utility company. The Newsweek listing is based on an analysis of a company's corporate social responsibility, as well as a public survey.

• Eversource received the 2019 Department of Defense Employer Support Freedom Award, the highest employer award given by the U.S. government, recognizing its support of employees who are serving our country.

• Eversource received the Boston Business Journal's Corporate Citizenship Award as one of the most charitable companies in Massachusetts.

• The U.S. EPA/DOE selected Eversource to receive the ENERGY STAR Partner of the Year Sustained Excellence Award for leadership in energy efficiency.

• Eversource received an EEI Emergency Recovery Award for restoration work following the damage caused by two tornadoes that struck Cape Cod in July 2019.

• Eversource was selected as a "most honored" company in Institutional Investor magazine's survey of some 1,500 portfolio managers and investment analysts. Eversource placed as the #1 or #2 utility in the Best Investor Relations Program, Best CFO, Best IR Professional, Best ESG Metrics, and Best in Corporate Governance Categories.

Achievement of the 2019 performance goals, additional accomplishments and the Committee's assessment Eversource's and executive's performance are more fully described in the section below titled "2019 Annual Incentive Program." Specific decisions regarding executive compensation based upon the Committee's assessment of Eversource's and executive's performance and market data are also described below.

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Pay for Performance Philosophy

The Committee links the compensation of the executive officers, including the Named Executive Officers, to performance that will ultimately benefit Eversource's customers and shareholders. Eversource's compensation program is intended to attract and retain the best executive talent in the industry, motivate its executives to meet or exceed specific stretch financial and operational goals each year, and compensate its executives in a manner that aligns compensation directly with performance. Eversource strives to provide executives with base salary, performance-based annual incentive compensation, and performance-based long-term incentive compensation opportunities that are competitive with market practices and that reward excellent performance.

Summary Compensation Table Versus Realized Pay Comparison - James J. Judge - Eversource CEO

Since the date of his election as CEO of Eversource, the realized pay of Mr. Judge has been substantially less than his total compensation as reported in the Summary Compensation Table (his reported pay). This is because a large portion of Mr. Judge's reported pay consists of the annual increase in Mr. Judge's pension benefit, which as noted below, and in the section captioned, "Mr. Judge's Pension Benefit," does not represent actual earnings. This is because the reported compensation as required by the SEC's regulation differs from an executive's actual earnings, referred to as "realized pay." Realized pay, on the other hand, is the amount that Mr. Judge actually received during the three fiscal years noted. As a result, Eversource believes that it is useful to compare his realized pay for each year with his reported pay for the same period as illustrated in the chart below.

Definitions for purposes of the preceding figures:

1.    SEC Summary Compensation Table Compensation: (i) base salary paid in each year, (ii) actual bonus earned for each year, (iii) the grant date amount of LTI awards, (iv) value of actuarial change in pension value, and (v) all other compensation as shown in the Summary Compensation Table for each year.

2.    Realized Pay: (i) base salary paid in each year; (ii) the actual bonus earned for each year; (iii) for performance shares and RSUs, the actual value earned upon vesting; and (iv) the value of all other compensation realized in each year, including 401k matching contribution, financial planning services, and a company-leased vehicle. Realized pay for Eversource's CEO does not assign a value to pension benefits or change in benefit value, as pension benefits were not realized in 2017, 2018, or 2019.

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Executive Compensation Governance

What Eversource DOES:		What Eversource DOESN'T do:
ü	Pay for Performance	û	No tax gross-ups in any new or materially amended executive compensation agreements
ü	Share ownership and holding guidelines	û	No hedging, pledging or similar transactions by Eversource executives and Trustees
ü	Balanced incentive metrics	û	No liberal share recycling
ü	Delivery of the majority of incentive compensation opportunity in long-term equity	û	No dividends on equity awards before vesting
ü	Broad financial and personal misconduct clawback policy relating to incentive compensation	û	No discounts or repricing of options or SARs
ü	Double-trigger change in control vesting provisions	û	No change in control agreements since 2010
ü	Shareholder engagement meetings between management and shareholders that discuss compensation governance
ü	100 percent of long-term incentive compensation paid in stock
ü	Independent compensation consultant
ü	Annual Say-on-Pay vote
ü	Payout limitations on incentive awards
ü	Limited executive trading window

• Eversource's executive share ownership and holding guidelines noted in this CD&A emphasize the importance of aligning management with shareholders. Under the share ownership guidelines, which require Eversource's Chief Executive Officer to hold shares equal to six times base salary, Eversource requires its executives to hold 100 percent of the shares awarded under the stock compensation program until the share ownership guidelines have been met.

• Eversource's incentive plan includes a clawback provision that requires its executives and other participants to reimburse Eversource for incentive compensation received, not only if earnings are subsequently required to be restated as a result of noncompliance with accounting rules caused by fraud or misconduct, but also for a material violation of Eversource's Code of Business Conduct or material breach of a covenant in an employment agreement. The Plan also imposes limits on awards and on compensation of Eversource Trustees and prohibits repricing of awards and liberal share recycling.

• Eversource prohibits gross-ups in all new or materially amended executive compensation agreements.

• Eversource has a "no hedging and no pledging" policy that prohibits the purchase of financial instruments or otherwise entering into any transactions that are designed to have the effect of hedging or offsetting any decrease in the market value of Eversource common shares.

• Eversource's employment agreements and incentive plan require "double-trigger" change in control to accelerate compensation.

• Eversource's Compensation Committee annually assesses the independence of its compensation consultant, Pay Governance LLC (Pay Governance), which is retained directly by the Committee. Pay Governance performs no other consulting nor provides services for Eversource and has no relationship with Eversource that could result in a conflict of interest. At its February 5, 2020 meeting, the Committee concluded that Pay Governance is independent and that no conflict of interest exists between Pay Governance and Eversource.

Named Executive Officers

The executive officers of CL&P listed in the Summary Compensation Table and whose compensation is discussed in this CD&A are referred to as the "Named Executive Officers" or "NEOs" under SEC regulations. For 2019, CL&P's Named Executive Officers were:

• James J. Judge, Chairman, President and Chief Executive Officer of Eversource Energy and Chairman of the Board of CL&P

• Philip J. Lembo, Executive Vice President and Chief Financial Officer of Eversource Energy and CL&P

• Werner J. Schweiger, Executive Vice President and Chief Operating Officer of Eversource Energy and Chief Executive Officer of CL&P

• Gregory B. Butler, Executive Vice President and General Counsel of Eversource Energy and CL&P

• Joseph R. Nolan, Jr., Executive Vice President - Strategy, Customer and Corporate Relations of Eversource Energy and Eversource Service

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Overview of the Compensation Program

The Role of the Compensation Committee. The Eversource Board of Trustees has delegated to the Compensation Committee overall responsibility for establishing the compensation program for those senior executive officers, whom are referred to in this CD&A as "executives" and whom are deemed to be "officers" under the SEC's regulations that determine the persons whose compensation is subject to disclosure. In this role, the Committee sets compensation policy and compensation levels, reviews and approves performance goals and evaluates executive performance. Although this CD&A refers principally to compensation for the Named Executive Officers, the same compensation principles and practices apply to all executives. The compensation of Eversource's Chief Executive Officer is subject to the further review and approval of all of the independent Eversource Trustees.

Elements of Compensation. Total direct compensation consists of three elements: base salary, annual cash incentive awards and long-term equity-based incentive awards. Indirect compensation is provided through certain retirement, perquisite, severance, and health and welfare benefit programs.

Eversource's Compensation Objectives. The objectives of Eversource's compensation program are to attract and retain superior executive talent, motivate executives to achieve annual and long-term performance goals set each year, and provide total compensation opportunities that are competitive with market practices. With respect to incentive compensation, the Committee believes it is important to balance short-term goals, such as producing earnings, with longer-term goals, such as long-term value creation for shareholders and maintaining a strong balance sheet. The Committee also places great emphasis on operating performance and customer service. Eversource's compensation program utilizes performance-based incentive compensation to reward individual and corporate performance and to align the interests of executives with Eversource Energy's customers and shareholders. The Committee continually increases expectations to motivate executives and employees to achieve continuous improvement in carrying out their responsibilities to customers to deliver energy and water reliably, safely, mindful of the environment and Eversource employees, and at a reasonable cost, while providing an above-average total return to Eversource shareholders.

Setting Compensation Levels. To ensure that Eversource achieves its goal of providing market-based total direct compensation levels to attract and retain top quality management, the Committee provides executives with target compensation opportunities approximately equal to median compensation levels for executive officers of companies in the utility industry comparable to Eversource in size. To achieve that goal, the Committee and its independent compensation consultant work together to determine the market values of executive direct compensation elements (base salaries, annual incentives and long-term incentives), as well as total compensation, by using competitive market compensation data. The Committee reviews competitive compensation data obtained from utility and general industry surveys and a specific group of peer utility companies. Incumbent compensation levels may be set below the market median for those executives who are new to their roles, while long-tenured, high performing executives may be compensated above median. The review by Pay Governance performed in late 2019 indicated that Eversource's aggregate executive compensation levels were aligned with median market rates.

Role of the Compensation Consultant. The Committee has retained Pay Governance as its independent compensation consultant. Pay Governance reports directly to the Committee and does not provide any other services to Eversource. With the consent of the Committee, Pay Governance works cooperatively with Eversource's management to develop analyses and proposals for presentation to the Committee. The Committee generally relies on Pay Governance for peer group market data and information as to market practices and trends to assess the competitiveness of the compensation Eversource pays to its executives and to review the Committee's proposed compensation decisions.

Pay Governance Independence. In February 2020, the Committee assessed the independence of Pay Governance pursuant to SEC and NYSE rules, and concluded that it is independent and that no conflict of interest exists that would prevent Pay Governance from independently advising the Committee. In making this assessment, the Committee considered the independence factors enumerated in Rule 10C-1(b) under the Securities Exchange Act of 1934, as well as the written representations of Pay Governance that Pay Governance does not provide any other services to Eversource, the level of fees received from Eversource as a percentage of Pay Governance's total revenues, the policies and procedures employed by Pay Governance to prevent conflicts of interest, and whether the individual Pay Governance advisers with whom the Committee consulted own any Eversource Energy common shares or have any business or personal relationships with members of the Committee or the Eversource executives.

Role of Management. The role of Eversource's management, and specifically the roles of Eversource's Chief Executive Officer and the Executive Vice President of Human Resources and Information Technology, are to provide current compensation information to the compensation consultant and analyses and recommendations on executive compensation to the Committee based on the market value of the position, individual performance, experience and internal pay equity. Eversource's Chief Executive Officer also provides recommendations on the compensation for the other Eversource Named Executive Officers. None of the executives makes recommendations that affect his or her individual compensation.

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MARKET ANALYSIS

The Compensation Committee seeks to provide executives with target compensation opportunities using a range that is approximately equal to the median compensation levels for executive officers of utility companies comparable to Eversource. Set forth below is a description of the sources of the compensation data used by the Committee when reviewing 2019 compensation:

• Competitive compensation survey data. The Committee reviews compensation information obtained from surveys of diverse groups of utility and general industry companies that represent Eversource's market for executive officer talent. Utility industry data serve as the primary reference point for benchmarking officer compensation and are based on a defined peer set, as discussed below, while general industry data are derived from compensation consultant surveys and serve as a secondary reference point. General industry data are used for staff positions and are size-adjusted to ensure a close correlation between the market data and Eversource's scope of operations. The Committee references this information, which it obtains from Pay Governance, to evaluate and determine base salaries and incentive opportunities.

• Peer group data. In support of executive pay decisions, the Committee consulted with Pay Governance, which provided the Committee with a competitive assessment analysis of Eversource's executive compensation levels as compared to the 20 peer group companies listed in the table below. This peer group was chosen because these companies are and continue to be similar to Eversource Energy in terms of size, business model and long-term strategies.

Alliant Energy Corporation	DTE Energy Company	PPL Corporation
Ameren Corporation	Edison International	Public Service Enterprise Group, Inc.
American Electric Power Co., Inc.	Entergy Corporation	SCANA Corp. (2018)
CenterPoint Energy, Inc.	FirstEnergy Corp.	Sempra Energy
CMS Energy Corp.	NiSource Inc.	WEC Energy Group, Inc.
Consolidated Edison, Inc.	PG&E Corporation	Xcel Energy Inc.
Dominion Energy, Inc.	Pinnacle West Capital Corporation

The Committee reviews the appropriateness of the peer group periodically and adjusts the target percentages of annual and long-term incentives based on the survey data and recommendations from Eversource's CEO, after discussion with the compensation consultant, to ensure that they are approximately equal to competitive median levels.

The Committee periodically reviews the general market for supplemental benefits and perquisites using utility and general industry survey data, including data obtained from companies in the peer group.

MIX OF COMPENSATION ELEMENTS

Eversource targets the mix of compensation for its Chief Executive Officer and its other Named Executive Officers so that the percentages of each compensation element are approximately equal to the competitive median market mix. The mix is heavily weighted toward incentive compensation, and incentive compensation is heavily weighted toward long-term compensation. Since the most senior positions have the greatest responsibility for implementing the long-term business plans and strategies, a greater proportion of total compensation is based on performance with a long-term focus.

The Committee determines the compensation for each executive based on the relative authority, duties and responsibilities of the executive. Eversource's Chief Executive Officer's responsibilities for the strategic direction and daily operations and management of Eversource are greater than the duties and responsibilities of the other executives. As a result, Eversource's Chief Executive Officer's compensation is higher than the compensation of those other executives. Assisted by the compensation consultant, the Committee regularly reviews market compensation data for executive officer positions similar to those held by Eversource's executives, including its Chief Executive Officer.

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The following table sets forth the contribution to 2019 Total Direct Compensation (TDC) of each element of compensation at target, reflected as a percentage of TDC, for the Named Executive Officers. The percentages shown in this table are at target and therefore do not correspond to the amounts appearing in the Summary Compensation Table.

	Percentage of TDC at Target
			Long-Term Incentives
	Base Salary	Annual Incentive (1)	Performance Shares (1)
Named Executive Officer				RSUs (2)	TDC
James J. Judge	15	17	34	34	100
Philip J. Lembo	26	20	27	27	100
Werner J. Schweiger	26	20	27	27	100
Gregory B. Butler	29	19	26	26	100
Joseph R. Nolan, Jr.	29	19	26	26	100
NEO average, excluding CEO	28	20	26	26	100

(1) The annual incentive compensation element and performance shares under the long-term incentive compensation element are performance-based.

(2) Restricted Share Units (RSUs) vest over three years contingent upon continued employment.

Results of Eversource's 2019 Say-on-Pay Vote. Eversource provides its shareholders with the required opportunity to cast the annual advisory vote on executive compensation (a "Say-on-Pay" proposal). At Eversource's Annual Meeting of Shareholders held on May 1, 2019, 88 percent of the votes cast on the Say-on-Pay proposal were voted to approve the 2018 compensation of the Named Executive Officers, as described in Eversource's 2019 proxy statement. Eversource's Say-on-Pay results, along with utility and general industry peers, are reviewed by the Committee annually to help assess whether Eversource shareholders continue to deem the executives' compensation to be appropriate. The Committee has and will continue to consider the outcome of Eversource's Say-on-Pay votes when making future compensation decisions for the Named Executive Officers.

ELEMENTS OF 2019 COMPENSATION

Base Salary

Base salary is designed to attract and retain key executives by providing an element of total compensation at levels competitive with those of other executives employed by companies of similar size and complexity in the utility and general industries. In establishing base salary, the Compensation Committee relies on compensation data obtained from independent third-party surveys of companies and from an industry peer group to ensure that the compensation opportunities Eversource offers are capable of attracting and retaining executives with the experience and talent required to achieve its strategic objectives. Adjustments to base salaries are generally made on an annual basis except in instances of promotions.

When setting or adjusting base salaries, the Committee considers annual executive performance appraisals; market pay movement across industries (determined through market analysis); targeted market pay positioning for each executive; individual experience; strategic importance of a position; recommendations of Eversource's Chief Executive Officer; and internal pay equity.

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Incentive Compensation

Annual incentive and long-term incentive compensation are provided under Eversource's 2018 Incentive Plan. The annual incentive program provides cash compensation intended to reward performance under Eversource's annual operating plan. The long-term stock-based incentive program is designed to reward demonstrated performance and leadership, motivate future performance, align the interests of the executives with those of shareholders, and retain executives during the term of grants. The annual and long-term programs are designed to strike a balance between Eversource's short- and long-term objectives so that the programs work in tandem.

In addition to the specific performance goals, the Committee assesses other factors, as well as the executives' roles and individual performance and then makes annual incentive program awards at the levels and amounts disclosed in this CD&A.

RISK ANALYSIS OF EXECUTIVE COMPENSATION PROGRAM

The overall compensation program includes a mix of compensation elements ranging from a fixed base salary that is not at risk to annual and long-term incentive compensation programs intended to motivate executives and eligible employees to achieve individual and corporate performance goals that reflect an appropriate level of risk. The fundamental objective of the compensation program is to foster the continued growth and success of Eversource's business. The design and implementation of the overall compensation program provides the Committee with opportunities throughout the year to assess risks within the compensation program that may have a material effect on Eversource and its shareholders.

The Compensation Committee assesses the risks associated with the executive compensation program on an ongoing basis by reviewing the various elements of incentive compensation. The annual incentive program is designed to ensure an appropriate balance between individual and corporate goals, which were deemed appropriate and supportive of Eversource's annual business plan. Similarly, the long-term incentive program is designed to ensure that the performance metrics were properly weighted and supportive of Eversource's strategy. The Committee reviewed the overall compensation program in the context of risks identified in the annual operating plan. The annual and long-term incentive programs were designed to include mechanisms to mitigate risk. These mechanisms include realistic goal setting and discretion with respect to actual payments, in addition to:

• A mix of annual and long-term performance awards to provide an appropriate balance of short- and long-term risk and reward horizon;

• A variety of performance metrics, including financial, operational, customer service, ESG, diversity and safety goals and other strategic initiatives for annual performance awards to avoid excessive focus on a single measure of performance;

• Metrics in Eversource's long-term incentive compensation program that use earnings per share growth and relative total shareholder return, which are both robust measures of shareholder value and which reduce the risk that employees might be encouraged to pursue other objectives that increase risk or reduce financial performance;

• The provisions of Eversource's annual and long-term incentive programs, which cap awards at 200 percent of target;

• Expansive clawback provisions on incentive compensation, including clawback for material violations of the Eversource Code of Business Conduct; and

• Stock ownership requirements for all executives, including the Named Executive Officers, and prohibitions on hedging, pledging and other derivative transactions related to Eversource common shares.

Based on these factors, the Compensation Committee and Eversource's Board of Trustees believe the overall compensation program risks are mitigated to reduce overall compensation risk.

2019 ANNUAL INCENTIVE PROGRAM ASSESSMENT

In February 2019, the Committee established the terms of the 2019 Annual Incentive Program. As part of the overall program, and after consulting with Pay Governance, the Committee set target award levels for each of the Named Executive Officers that ranged from 65 percent to 120 percent of base salary.

At the February 2019 meeting, the Committee determined that for 2019 it would continue to base 70 percent of the annual incentive performance goals on Eversource's overall financial performance and 30 percent of the annual performance goals on Eversource's overall operational performance. The Committee also determined the specific goals that would be used to assess performance, with potential ratings on each goal ranging from 0 percent to 200 percent of target. The Committee assigned weightings to each of these specific goals. For the financial component, the following goals were used: earnings per share, weighted at 60 percent, dividend growth, weighted at 10 percent, and advancement of strategic growth initiatives and regulatory outcomes, weighted at 30 percent. For the operational component, the Committee used the following goals: combined service reliability and restoration goals, weighted at 50 percent, and combined safety ratings, gas service response, diversity promotions and hires of leadership employee positions goals, and sustainability and customer and clean energy initiatives, weighted at 50 percent.

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In establishing the individual annual performance goals, the Committee sets stretch goals for both the Financial and Operational goals, many of which do not represent threshold or target award goals, but require superior performance in order to be met. As a result, achieving these goals will justify an assessment beyond the target amount that is set for computing results.

2019 Performance Goals

At the December 2019 meeting of the Committee, management provided an initial review of Eversource's 2019 performance, followed in February 2020 by a full assessment of the performance goals, the additional accomplishments noted below under the caption "Additional Factors" and the overall performance of Eversource and the executives. In addition to these meetings, the Committee and the Eversource Board were provided updates during 2019 on corporate performance. At the February 5, 2020 meeting, the Committee determined, based on its assessment of the financial and operational performance goals, to set the level of achievement of combined financial and operational performance goals results at 188 percent, reflecting the exceptionally strong performance of Eversource and the executive team. In arriving at this determination, the Committee determined that the financial performance goals result was 185 percent and the operational performance goals result was 192 percent. Eversource's Chief Executive Officer recommended to the Committee awards for the executives (other than himself) based on his assessment of each executive's individual performance towards achievement of the performance goals and the additional accomplishments of Eversource, together with each executive's contributions to the overall performance of Eversource. The actual awards determined by the Committee were also based on the same criteria.

Financial Performance Goals Assessment

• FINANCIAL PERFORMANCE: Eversource's non-GAAP earnings per share in 2019, which excludes the NPT impairment charge, increased by 6.2 percent when compared to GAAP earnings per share in 2018, and exceeded the established goal of $3.42. Eversource was able to achieve earnings through effective management of the 2019 operating plan on a day by day basis and by overcoming several challenges to plan achievement, including higher than plan operation and maintenance storm restoration expenses and the impact of the dilution of a very successful equity issuance.

The Committee discussed at length the earnings per share goal, and to what extent the NPT impairment charge, which reduced GAAP earnings by $0.64 per share, should affect the earnings goal assessment. This discussion included consideration of the nature, timing, cause, mitigation and overall effect of the impairment charge on Eversource’s 2019 financial performance. The Committee determined the earnings per share goal to have attained a 180 percent performance result.

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• DIVIDENDS PAID: Eversource increased its dividend to $2.14 per share, a 5.9 percent increase from the prior year, significantly above the utility industry's median dividend growth of 5.1 percent. The Committee determined this goal to have attained a 170 percent performance result.

    

• CLEAN ENERGY: Eversource advanced its strategic growth initiatives in 2019. Eversource expanded the offshore wind partnership with Ørsted, the global leader of offshore wind development, through the acquisition of the Northeast U.S. assets of Deepwater Wind. The partnership with Ørsted successfully bid into the New York clean energy request for proposal and was awarded a contract for 880 megawatts of offshore wind power with the Sunrise Wind project, and the partnership advanced the New London State Pier agreement to support offshore wind construction. The 1,714 megawatts that the partnership has under contract makes the Eversource/Ørsted partnership the largest developer of offshore wind in North America. Eversource accelerated the original five-year electric vehicle charging program in Massachusetts to three years, and the program met its 2019 targets, and Eversource commenced the construction process on two energy storage projects in Massachusetts. These projects will substantially improve system reliability with innovative clean energy solutions. The Committee determined this goal to have attained a 200 percent performance result.

Operational Performance Goals Assessment

• RELIABILITY PERFORMANCE: Eversource's total electric system reliability performance significantly exceeded that of its peers and was Eversource's best performance ever. Average months between interruptions equaled 21.6 months, significantly exceeding the performance zone established by the Committee. Eversource's results are in the top decile of industry peers. The Committee determined this goal to have attained a 200 percent performance result.

    

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• RESTORATION PERFORMANCE: System average restoration duration time equaled 59.2 minutes, also significantly exceeding the performance zone established by the Committee and also reflecting Eversource's best year ever and top decile performance in the industry. The Committee determined this goal to have attained a 200 percent performance result.

    

• SAFETY: Eversource achieved the safety performance goal of between 0.5 and 0.9 DART per 100 employees; DART equaled 0.7 in 2019, within the goal's established performance zone and better than its peers. The Committee determined this goal to have attained a 150 percent performance result.

    

• GAS EMERGENCY RESPONSE: On-time response to gas customer emergency calls was 99.7 percent, which exceeded the goal's upper range performance zone of 99.2 percent to 99.6 percent. The Committee determined this goal to have attained a 200 percent performance result.

    

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• DIVERSITY: In 2019, 41 percent of new Eversource hires and promotions into leadership roles were women or people of color, exceeding the goal of 40 percent. The Committee determined this goal to have attained a 175 percent performance result.

• SUSTAINABILITY: Eversource established a new goal in 2019, which was to be in the 75th percentile of a peer group of comparably sized U.S. utilities whose ESG performance is assessed by the two leading sustainability rating firms. Eversource's average score ranked in the top decile of the peer group. The Committee determined this goal to have attained a 200 percent performance result.

• CUSTOMER: Eversource continued its programs to transform the Eversource customer experience, launching a new mobile app, improving the accuracy of estimated time of service restoration during outages to 92 percent, and increasing digital customer interaction to 85.4 percent, all of which had a positive impact on customer satisfaction. The Committee determined this goal to have attained a 175 percent performance result.

• CLEAN ENERGY: In addition to the significant progress in offshore wind, Eversource's electric vehicle charging program met its 2019 goal, condensing its five-year implementation to three years and advancing two energy storage projects. Eversource also maintained its energy efficiency status as the leading energy efficiency provider in the nation per the American Council for Energy Efficient Economy. The Committee determined this goal to have attained a 200 percent performance result.

2019 Annual Incentive Program Performance Assessments

Financial Performance Goals

Category	2019 Goal	Eversource Performance	Assessment
Earnings Per Share	$3.42 earnings per share	Exceeded: GAAP earnings per share for 2019 equaled $2.81 per share. Non-GAAP earnings per share, excluding NPT impairment charge, increased by 6.2% over 2018 to $3.45	180%
Dividend Growth	Increase dividend beyond industry average	Exceeded: Increased to $2.14 per share, a $0.12 increase and 5.9% growth, exceeding the industry median of 5.1%	170%
Strategic Growth Initiatives	Advancement of Key Strategic Projects and Regulatory Outcomes	Exceeded: Significantly advanced Eversource's financial strategy and status as a clean energy leader through the major expansion of the offshore wind partnership with Ørsted. Temporary rates have been successfully negotiated in New Hampshire. Major storm costs recovered in all three states	200%
Weightings = Earnings Per Share: 60%; Dividend Growth: 10%; Strategic Growth Initiatives: 30%

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Operational Performance Goals

Category	2019 Goal	Eversource Performance	Assessment
Reliability - Average Months Between Interruptions (MBI)	Achieve MBI of within 15.5 to 18.5 months	Exceeded: MBI = 21.6 months. Best performance ever, and in the top decile of the industry peer group	200%
Average Restoration Duration (SAIDI)	Achieve SAIDI of 64 to 77 minutes	Exceeded: SAIDI = 59.2 minutes. Best performance ever, and in the top decile of the industry group	200%
Safety Rate (Days Away Restricted Time (DART))	0.5 - 0.9 days away/restricted	Achieved: 0.7 DART - Within performance range of the goal and exceeding industry peers	150%
Gas Service Response	99.2% - 99.6%	Exceeded: 99.7%; Exceeded performance range and ahead of industry average	200%
Diverse Leadership	40% diverse hires or promotions of leadership level	Exceeded: 41% - Performed above the goal, which was set 3% higher from 2018	175%
Sustainability Ranking	75th percentile vs US peer companies	Exceeded: At an average 94% percentile, Eversource outperformed the peer group and is well into the first quartile.	200%
Transform the Customer Experience	Launch new mobile app; increase accuracy of restoral time and customer digital engagement	Exceeded: Launched mobile app with strong results, estimated times for restoration given to customers were well managed 92% of the time, and customer digital engagement finished above the goal at 85.4%	175%
Clean Energy Execution	Successfully advance and execute clean energy initiatives	Exceeded: Significant progress with energy storage and electric vehicle projects. Energy efficiency programs continue to be recognized nationally for excellence	200%
Weightings = Reliability and Restoration: 50%; Safety, Gas Response, Diversity, Sustainability and Key Initiatives: 50%

Performance Goals Assessment

Financial Performance at 185% (weighted 70%)	130%
Operational Performance at 192% (weighted 30%)	58%
Overall Performance	188%

Additional Factors

2019 was a year when Eversource achieved its long-term vision to be broadly recognized as the Best Energy Company in the nation by the year 2020. Eversource is now strategically well positioned as a leading catalyst for Clean Energy in the country. The following important financial, strategic, operational, environmental and customer-focused results were considered by the Committee in assessing Eversource's overall financial and operational performance, but were not given specific weightings or assigned a specific performance assessment score:

• Eversource advanced Diversity & Inclusion through continued leadership commitment, and Active Councils and Business Resource Groups. Eversource was recognized for its commitment to advancing women in the workplace, earning a spot on the 2019 Bloomberg Gender-Equality Index.

• Eversource was named the #1 utility company by Forbes/JUST Capital for its commitment to ethical leadership, positive impact on the environment, treatment of customers, fair pay and benefits for employees, equal opportunity, and shareholder return.

• Eversource was named as the #1 energy and utilities company on Newsweek's Most Responsible Companies list; this award is based upon an analysis of companies' corporate social responsibility as well as a public survey.

• Eversource continued its ranking as the national leader in energy efficiency as measured by the American Council for an Energy Efficient Economy.

• Eversource received an EEI Emergency Recovery Award for restoration work following the damage caused by two tornadoes that struck Cape Cod in July 2019.

• Eversource was designated as a "most honored" company in Institutional Investor magazine's survey of some 1,500 portfolio managers and investment analysts. Ten percent of companies included in the survey earned such a designation. Eversource placed either first or second in five of the seven utility company categories.

• Eversource's 2019 Employee Pulse Survey reported significantly higher engagement by employees. Survey scores continue to improve, increasing by 11 percent over the 2018 survey and 22 percent over the 2016 survey.

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• Eversource achieved two mutually beneficial collective bargaining outcomes ahead of contract expiration dates.

• Eversource's 2019 charitable giving totaled $18.3 million, including major event lead sponsorships for the Eversource Walk for Children's Hospital, Eversource Walk and 5K Run for Easterseals New Hampshire, Mass General Cancer Center/Eversource Every Day Amazing Race, Eversource Hartford Marathon, Travelers Championship, and the Special Olympics in Connecticut and New Hampshire.

Individual Executives' Performance Factors Considered by the Committee

It is the Committee's philosophy to provide incentives for Eversource executives to work together as a highly effective, integrated team to achieve or exceed the financial, operational, safety, customer, sustainability, strategic and diversity goals and objectives. The Committee also reviews and assesses individual executive performance. The Committee based the annual incentive payments on team performance and the Committee's assessment of each executive's individual performance in supporting the performance goals, additional achievements, and Eversource's overall performance. With respect to Eversource's Chief Executive Officer, the Committee and all other independent Eversource Trustees assessed the performance of the Chief Executive Officer. Based on the recommendations of the Chief Executive Officer as to executives other than himself, the Committee assessed the performance of the Named Executive Officers to determine the individual incentive payments as disclosed in the Summary Compensation Table. Based on the Committee's review, which included its assessment of the performance goals, the significant other accomplishments of Eversource, and the overall performance of Eversource and each of the Named Executive Officers, considered in its totality by the Committee to have been superior, the Committee approved annual incentive program payments for the Named Executive Officers at levels that ranged from 175 percent to 200 percent of target. These payments reflected the individual and team contributions of the Named Executive Officers in achieving the goals and the additional accomplishments and Eversource's overall performance.

In determining Mr. Judge's annual incentive payment of $3,000,000, which was 188 percent of target and which reflects his and Eversource's transformational 2019 performance, the Committee and the Board considered the totality of Eversource's success in accomplishing the goals set by the Committee, the additional accomplishments of Eversource, and the superior leadership of Mr. Judge in continuing to both challenge the Eversource workforce to be broadly recognized as the best energy company in the nation by 2020 and leading Eversource in meeting that challenge.

2019 Annual Incentive Program Awards
Named Executive Officer	Award
James J. Judge	$	3,000,000
Philip J. Lembo	1,000,000
Werner J. Schweiger	1,050,000
Gregory B. Butler	950,000
Joseph R. Nolan, Jr.	740,000

Long-Term Incentive Program

General

Eversource's long-term incentive program is intended to focus on Eversource's longer-term strategic goals and to help retain its executives. A new three-year program commences every year. For the three programs described below, each executive's target long-term incentive opportunity consisted of 50 percent Performance Shares and 50 percent RSUs. For the 2021 - 2023 Program and as set forth below, the target opportunity will consist of 75 percent Performance Shares and 25 percent RSUs. Performance Shares are designed to reward long-term achievements as measured against pre-established performance measures. RSUs are designed to provide executives with an incentive to increase the value of Eversource common shares in alignment with shareholder interests, while also serving as a retention component for executive talent. Eversource believes these compensation elements create a focus on continued Eversource and share price growth to further align the interests of Eversource's executives with the interests of Eversource's shareholders.

Performance Share Grants

General

Performance Shares are designed to reward future financial performance, measured by long-term earnings growth and shareholder returns over a three-year performance period, therefore aligning management compensation with performance. Performance Shares are granted as a target number of Eversource common shares. The number of Performance Shares is determined by dividing the target grant value in dollars by the average daily closing prices of Eversource common shares on the New York Stock Exchange for the ten business days preceding the grant date and rounding to the nearest whole share. Until the end of the performance period, the value of dividends that would have been paid with respect to the Performance Shares had the Performance Shares been actual common shares will be deemed to be invested in additional Performance Shares, which remain at risk and do not vest until actual performance for the period is determined.

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Performance Shares under the 2018 - 2020 and 2019 - 2021 Programs

For the 2019 - 2021 Program, the Committee determined it would measure performance using: (i) average diluted earnings per share growth (EPSG); and (ii) relative total shareholder return (TSR) measured against the performance of companies that comprise the EEI Index. As in 2018 and 2017, the Committee selected EPSG and TSR as performance measures because the Committee continues to believe that they are generally recognized as the best indicators of overall corporate performance. Further, the Committee considers it a best practice to use a combination of relative and absolute metrics, with absolute EPS growth serving as a key input to shareholder value and relative TSR serving as the output.

The number of Performance Shares awarded at the end of the three-year period ranges from 0 percent to 200 percent of target, depending on EPSG and relative TSR performance as set forth in the performance matrix below. Performance Share grants are based on a percentage of annualized base salary at the time of the grant and measured in dollars. The target number of shares under the 2019 - 2021 Program ranged from 35 percent to 233 percent of base salary. EPSG ranges from 0 percent to 9 percent, while TSR ranges from below the 10th percentile to above the 90th percentile. The target award is 100 percent, which the Committee determined is challenging but achievable. As a result, vesting at 100 percent of target occurs at various combinations of EPSG and TSR performance. In addition, the value of any performance shares that actually vest may increase or decrease over the vesting period based on Eversource's share price performance. The number of performance shares granted at target were approved as set forth in the table below. The Committee and the independent members of the Eversource Board determined the Performance Share grants for Eversource's Chief Executive Officer. Based on input from the Chief Executive Officer, the Committee determined the Performance Share grants for each of the other executive officers, including the other Named Executive Officers.

For the 2018 - 2020 Program, the Committee used the same performance measures of EPSG and TSR and the same criteria used in the 2019 - 2021 Program described above.

The performance matrix set forth below describes how the Performance Share payout will be determined under the 2018 - 2020 and 2019 - 2021 Long-Term Incentive Programs and how the Performance Share payout was determined under the 2017 - 2019 Program. Three-year average EPSG is cross-referenced with the actual three-year TSR percentile to determine actual performance share payout as a percentage of target:

2017 - 2019, 2018 - 2020 and 2019 - 2021 Long-Term Incentive Programs Performance Share Potential Payout
Three-Year Average EPS Growth	Three-Year Relative Total Shareholder Return Percentiles
	Below 10th	20th	30th	40th	50th	60th	70th	80th	90th	Above 90th
9%	110%	120%	130%	140%	150%	160%	170%	180%	190%	200%
8%	100%	110%	120%	130%	140%	150%	160%	170%	180%	190%
7%	90%	100%	110%	120%	130%	140%	150%	160%	170%	180%
6%	80%	90%	100%	110%	120%	130%	140%	150%	160%	170%
5%	70%	80%	90%	100%	110%	120%	130%	140%	150%	160%
4%	60%	70%	80%	90%	100%	110%	120%	130%	140%	150%
3%	40%	50%	70%	80%	90%	100%	110%	120%	130%	140%
2%	20%	40%	60%	70%	80%	90%	100%	110%	120%	130%
1%	—	10%	40%	60%	70%	80%	90%	100%	110%	120%
0%	—	—	20%	30%	50%	70%	80%	90%	100%	110%
Below 0%	—	—	—	—	10%	20%	30%	40%	50%	60%

Long-Term Incentive Program Performance Share Grants at Target

Named Executive Officer	2018 - 2020 Performance Share Grant	2019 - 2021 Performance Share Grant
James J. Judge	48,912	46,249
Philip J. Lembo	10,682	10,103
Werner J. Schweiger	10,845	10,103
Gregory B. Butler	8,410	8,328
Joseph R. Nolan, Jr.	7,737	7,623

Results of the 2017 - 2019 Performance Share Program

The 2017 - 2019 Program, which used the same criteria used in the 2019 - 2021 Program described above, was completed on December 31, 2019. The actual performance level achieved under the Program was a three-year average adjusted EPS growth of 5.3 percent and a three-year total shareholder return at the 87th percentile, which when interpolated in accordance with the criteria established by the Committee in 2017 resulted in vesting performance share units at 150 percent of target. 2019 non-GAAP earnings per share, which exclude the NPT impairment charge, were the basis for performance level assessment. At its February 5, 2020 meeting, the Committee confirmed that the actual results achieved were calculated in accordance with established performance criteria. The number of Performance Shares awarded to the Named Executive Officers were approved as set forth in the table below.

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2017 – 2019 Long-Term Incentive Program Performance Share Awards
Named Executive Officer	Performance Share Award
James J. Judge	79,305
Philip J. Lembo	18,931
Werner J. Schweiger	19,232
Gregory B. Butler	14,875
Joseph R. Nolan, Jr.	13,015

The 2020 - 2022 and 2021 - 2023 Performance Share Programs

The Compensation Committee determined that for the 2020 - 2022 Program adjustments to the measurement criteria would be put into place increasing the level of performance required to reach a target (100 percent) grant award and adding additional performance levels for which no award of shares would be made. The Committee also determined that the 2021 - 2023 Performance Share Program will change such that 75 percent of the long-term incentive opportunity will consist of Performance Shares and 25 percent will consist of RSUs.

Restricted Share Units (RSUs)

General

Each RSU granted under the long-term incentive program entitles the holder to receive one Eversource common share at the time of vesting. All RSUs granted under the long-term incentive program vest in equal annual installments over three years. RSU holders are eligible to receive reinvested dividend units on outstanding RSUs held by them to the same extent that dividends are declared and paid on Eversource common shares. Reinvested dividend equivalents are accounted for as additional RSUs that accrue and are distributed with the common shares issued upon vesting of the underlying RSUs. Common shares, including any additional common shares in respect of reinvested dividend equivalents, are not issued for any RSUs that do not vest.

The Committee determined RSU grants for each executive officer participating in the long-term incentive program. RSU grants are based on a percentage of annualized base salary at the time of the grant. In 2019, the percentage used for each executive officer was based on the executive officer's position in Eversource and ranged from 40 percent to 238 percent of base salary. The Committee reserves the right to increase or decrease the RSU grant from target for each officer under special circumstances. The Committee and all other independent members of the Eversource Board determined the RSU grants for Eversource's Chief Executive Officer. Based on input from the Chief Executive Officer, the Committee determined the RSU grants for each of the other executive officers, including the other Named Executive Officers.

All RSUs are granted on the date of the Committee meeting at which they are approved. RSU grants are subsequently converted from a percent of salary into Eversource common share equivalents by dividing the value of each grant by the average closing price for Eversource common shares over the ten trading days prior to the date of the grant. RSU grants at 100 percent of target were approved as set forth in the table below.

	RSUs Granted
Named Executive Officer	2017	2018	2019
James J. Judge	48,259	48,912	46,249
Philip J. Lembo	11,520	10,682	10,103
Werner J. Schweiger	11,703	10,845	10,103
Gregory B. Butler	9,052	8,410	8,328
Joseph R. Nolan, Jr.	7,920	7,737	7,616

Clawbacks

If Eversource's earnings were to be restated as a result of noncompliance with accounting rules caused by fraud or misconduct, or if a plan participant engages in a willful material violation of Eversource's Code of Business Conduct or material corporate policy, or the breach of a material covenant in an employment agreement, as determined by the Eversource Board of Trustees, the participant will be required by the Eversource 2018 Incentive Plan to reimburse Eversource for incentive compensation awards received by them for that year.

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No Hedging and No Pledging Policy

Eversource has a long-standing policy prohibiting the purchase of any financial instruments or otherwise entering into transactions designed to have the effect of hedging or offsetting any decrease in the value of Eversource common shares or other Eversource equity securities or its subsidiaries by Eversource Trustees and executives, including exchange-traded options to purchase or sell Eversource securities (so-called "puts" and "calls") or financial instruments that are designed to hedge or offset any decrease in the market value of Eversource securities (including, but not limited to, prepaid variable forward contracts, equity swaps, collars and exchange funds). This policy also prohibits short sales, the holding of any Eversource common shares in a margin account, borrowing shares, selling future securities that establish a position that increases in value as the value of Eversource common shares decreases, or pledging Eversource's common shares. The policy applies to Trustees and executives but not to non-executives and does not apply to broad-based index funds or similar transactions.

Share Ownership Guidelines and Retention Requirements

The Committee has approved share ownership guidelines to further emphasize the importance of share ownership by Eversource officers. As indicated in the table below, the guidelines call for Eversource's Chief Executive Officer to own common shares equal to six times base salary, executive vice presidents to own a number of common shares equal to three times base salary, senior vice presidents to own common shares equal to two times base salary, and all other officers to own a number of common shares equal to one to one and one half times base salary. Officers and Eversource Trustees may only transact in Eversource common shares during approved trading windows and subject to continuing compliance with these share ownership guidelines.

Executive Officer	Base Salary Multiple
Chief Executive Officer	6
Executive Vice Presidents	3
Operating Company Presidents / Senior Vice Presidents	2
Vice Presidents	1 – 1.5

Eversource requires that its officers attain these ownership levels within five years. All Eversource officers, including Eversource's Named Executive Officers, have satisfied the share ownership guidelines or are expected to satisfy them within the applicable timeframe. Common shares, whether held of record, in street name, or in individual 401(k) accounts, and RSUs satisfy the guideline requirements to hold 100 percent of the net shares. Unvested performance shares do not count toward the ownership guidelines. In addition to the share ownership guidelines noted above, all officers must hold all the shares awarded under Eversource's incentive compensation plan until the share ownership guidelines have been met.

Other Benefits

Retirement Benefits

Eversource provides a qualified defined benefit pension program for certain officers, which is a final average pay program subject to tax code limits. Because of such limits, Eversource also maintain a supplemental non-qualified pension program. Benefits are based on base salary and certain incentive payments, which is consistent with the goal of providing a retirement benefit that replaces a percentage of pre-retirement income. The supplemental program compensates for benefits barred by tax code limits, and generally provides (together with the qualified pension program) benefits equal to approximately 60 percent of pre-retirement compensation (subject to certain reductions) for Messrs. Judge, Lembo, Schweiger and Nolan, and approximately 50 percent of such compensation for Mr. Butler. The supplemental program has been discontinued for newly-elected officers.

For certain participants, the benefits payable under the Supplemental Non-Qualified Pension Program differ from those described above. The program benefit payable to Mr. Schweiger is fully vested and is further reduced by benefits he is entitled to receive under previous employers' retirement plans.

Also see the narrative accompanying the "Pension Benefits" table and accompanying notes for more detail on the above program.

Mr. Judge's Pension Benefit

As an employee for more than 40 years, Mr. Judge's employee benefits include a pension benefit. Mr. Judge was elected to the position of President and Chief Executive Officer in 2016, such that 2017 was the first year that he served in his new position at the higher CEO compensation level. Since then there have been substantial increases over the past three years in the actuarial, formula-based present values of his pension benefit. These increases are disclosed in the Change in Pension Value and Non-Qualified Deferred Earnings column of the Summary Compensation Table. The methodology that is used to calculate the change in pension value is based upon applicable accounting rules and is influenced up or down by external values, such as assumptions regarding life expectancy and changes in the discount rate determined each year. These variables are functions of factors that do not relate to Eversource and executive performance, are outside the control of the Committee, and may or may not impact the amounts that will actually be paid, as such variables and assumptions may change from time to time. The calculation of Pension Value is very sensitive to interest rate levels. Recent very low interest rates have resulted in a very low discount rate and is a major reason for the large increase in Mr. Judge's Change in Pension Value. The accounting-based increase for Mr. Judge, while

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representing a substantial portion of his 2017, 2018 and 2019 total compensation disclosed in the SEC Total column of the Summary Compensation Table, resulted in no actual 2017 to 2019 W-2 earnings for him.

401(k) Benefits

Eversource offers a qualified 401(k) program for all employees, including executives, subject to tax code limits. After applying these limits, the program provides a match of 50 percent of the first 8 percent of eligible base salary, up to a maximum of $11,200 per year for Messrs. Judge, Lembo, Schweiger and Nolan. For Mr. Butler, the program provides a match of 100 percent of the first 3 percent of eligible base salary, up to a maximum of $8,400 per year.

Deferred Compensation

Eversource offers a non-qualified deferred compensation program for its executives. In 2019, the program allowed deferral of up to 100 percent of base salary, annual incentives and long-term incentive awards. The program allows participants to select investment measures for deferrals based on an array of deemed investment options (including certain mutual funds and publicly traded securities).

See the Non-Qualified Deferred Compensation Table and accompanying notes for additional details on the above program.

Perquisites

Eversource provides executives with limited financial planning benefits, vehicle leasing and access to tickets to sporting events. The current level of perquisites does not factor into decisions on total compensation.

Contractual Agreements

Eversource maintains contractual agreements with all of its Named Executive Officers that provide for potential compensation in the event of certain terminations, including termination following a Change in Control. Eversource believes these agreements are necessary to attract and retain high quality executives and to ensure executive focus on Eversource business during the period leading up to a potential Change in Control. The agreements are "double-trigger" agreements that provide executives with compensation in the event of a Change in Control followed by termination of employment due to one or more of the events set forth in the agreements, while still providing an incentive to remain employed with Eversource for the transition period that follows.

Under the agreements, certain compensation is generally payable if, during the applicable change in control period, the executive is involuntarily terminated (other than for cause) or terminates employment for "good reason." These agreements are described more fully in the tables following this CD&A under "Payments Upon Termination." Eversource has not entered into a Change in Control agreement with any executive since 2010.

Tax and Accounting Considerations

Section 162(m) of the Internal Revenue Code precludes a public corporation from taking an income tax deduction in any one year for compensation in excess of $1 million payable to its Named Executive Officers who are employed on the last day of the fiscal year, unless certain specific performance goals are satisfied. Until January 1, 2018, there was an exception to the $1 million limitation for performance-based compensation meeting certain requirements. This exception was repealed, effective for taxable years beginning after December 31, 2017, and the limitation on deductibility generally was expanded to include all Named Executive Officers. As a result, compensation paid to the Named Executive Officers in excess of $1 million per officer will not be deductible unless it qualifies for transition relief applicable to certain arrangements in place as of and not modified after November 2, 2017.

The Committee believes that the availability of a tax deduction for forms of compensation should be one of many factors taken into consideration of providing market-based compensation to attract and retain highly qualified executives. The Committee believes it is in Eversource's best interests to retain discretion to make compensation awards, whether or not deductible.

Eversource has adopted the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 718, Compensation-Stock Compensation. In general, Eversource and the Committee do not consider accounting considerations in structuring compensation arrangements.

Equity Grant Practices

Equity awards noted in the compensation tables are made annually at the February meeting of the Compensation Committee (subject to further approval by all of the independent members of Eversource's Board of Trustees of Eversource's Chief Executive Officer's award) when the Committee also determines base salary, annual incentive opportunities, long-term incentive compensation targets, and annual and long-term performance plan awards. The date of this meeting is chosen at least a year in advance, and therefore awards are not coordinated with the release of material non-public information.

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SUMMARY COMPENSATION TABLE

The table below summarizes the total compensation paid or earned by CL&P's principal executive officer (Mr. Judge), principal financial officer (Mr. Lembo) and the three other most highly compensated executive officers in 2019, determined in accordance with the applicable SEC disclosure rules (collectively, the Named Executive Officers). As explained in the footnotes below, the amounts reflect the economic benefit to each Named Executive Officer of the compensation item paid or accrued on behalf of the Named Executive Officers for the fiscal year ended December 31, 2019 in accordance with such rules. All salaries, annual incentive amounts and long-term incentive amounts shown for each Named Executive Officer were paid for all services rendered to Eversource Energy and its subsidiaries, including CL&P, in all capacities.

Name and Principal Position	Year	Salary		Stock Awards (1)		Non-Equity Incentive Plan (2)		Change in Pension Value and Non- Qualified Deferred Earnings (3)		All Other Compen- sation (4)		SEC Total		Adjusted SEC Total (5)
James J. Judge	2019	$	1,319,232	$	6,676,043	$	3,000,000	$	8,784,256	$	26,557	$	19,806,088	$	11,021,832
Chairman, President and Chief Executive Officer of Eversource Energy; Chairman of CL&P	2018	1,277,078		5,632,217		2,430,000		5,560,877		25,209		14,925,381		9,364,504
	2017	1,230,694		5,504,904		2,285,000		6,869,854		25,009		15,915,461		9,045,607
Philip J. Lembo	2019	680,579		1,458,368		1,000,000		1,318,800		20,390		4,478,137		3,159,337
Executive Vice President and Chief Financial Officer of Eversource Energy and CL&P	2018	648,271		1,230,032		765,000		1,535,216		21,685		4,200,204		2,664,988
	2017	613,847		1,314,086		700,000		1,246,325		21,485		3,895,743		2,649,418
Werner J. Schweiger	2019	692,694		1,458,368		1,050,000		2,218,536		21,846		5,441,444		3,222,908
Executive Vice President and Chief Operating Officer of Eversource Energy and CL&P	2018	658,271		1,248,802		815,000		538,978		53,896		3,314,947		2,775,969
	2017	634,078		1,334,961		775,000		1,225,581		21,418		3,991,038		2,765,457
Gregory B. Butler	2019	643,270		1,202,147		740,000		2,948,208		15,518		5,549,143		2,600,935
Executive Vice President and General Counsel of Eversource Energy and CL&P	2018	618,271		968,412		645,000		634,394		15,143		2,881,220		2,246,826
	2017	597,886		1,032,562		625,000		1,670,745		15,361		3,941,554		2,270,809
Joseph R. Nolan, Jr.	2019	589,616		1,100,380		774,000		3,283,296		20,388		5,767,680		2,484,384
Executive Vice President-Strategy, Customer and Corporate Relations of Eversource Energy and Eversource Service	2018	561,540		890,916		720,000		1,193,350		56,084		3,421,890		2,228,540
	2017	515,578		903,434		680,000		1,486,025		16,076		3,601,113		2,115,088

(1) Reflects the aggregate grant date fair value of restricted share units (RSUs) and performance shares granted in each fiscal year, calculated in accordance with FASB ASC Topic 718.

RSUs were granted to each Named Executive Officer in 2019 as long-term compensation, which vest in equal annual installments over three years. In 2019, each of the Named Executive Officers was also granted performance shares as long-term incentive compensation. These performance shares will vest based on the extent to which the two performance conditions described in the CD&A are achieved as of December 31, 2021. The grant date fair values for the performance shares, assuming achievement of the highest level of both performance conditions, are as follows: Mr. Judge: $5,080,453; Mr. Lembo: $1,109,815; Mr. Schweiger: $1,109,815; Mr. Butler: $914,831; and Mr. Nolan: $837,387.

Holders of RSUs and performance shares are eligible to receive dividend equivalent units on outstanding awards to the same extent that dividends are declared and paid on Eversource common shares. Dividend equivalent units are accounted for as additional common shares that accrue and are distributed simultaneously with those common shares that are issued upon vesting of the underlying RSUs and performance shares. No dividends are paid unless and until the underlying shares vest.

(2) Includes payments to the Named Executive Officers under the 2019 Annual Incentive Program: Mr. Judge: $3,000,000; Mr. Lembo: $1,000,000; Mr. Schweiger: $1,050,000; Mr. Butler: $740,000; and Mr. Nolan: $774,000.

(3) Includes the actuarial increase in the present value from December 31, 2018 to December 31, 2019 of the Named Executive Officers' accumulated benefits under all of the defined benefit pension programs and agreements, determined using interest rate and mortality rate assumptions consistent with those appearing in the footnotes to the Annual Report on Form 10-K for the fiscal year ended December 31, 2019. The Named Executive Officer may not be fully vested in such amounts. More information on this topic is set forth in the Pension Benefits table. There were no above-market earnings in deferred compensation value during 2019, as the terms of the Deferred Compensation Plan provide for market-based investments, including Eversource common shares. Mr. Judge was elected to the position of President and Chief Executive Officer of Eversource Energy in 2016, such that 2017 was the first year that he served in his more highly compensated position. This has resulted in substantial increases in the actuarial present value of his pension benefits. These accounting-based increases, while representing for Mr. Judge a substantial portion of his 2017 - 2019 total compensation disclosed in the SEC Total above, resulted in no actual W-2 earnings for him for these years.

(4) Includes matching contributions allocated by Eversource to the accounts of Named Executive Officers under the 401k Plan as follows: $11,200 for each of Messrs. Judge, Lembo and Schweiger and Nolan, and $8,400 for Mr. Butler. For Mr. Judge, the value shown includes financial planning services valued at $5,000 and $10,357 paid by Eversource for a company-leased vehicle. For Mr. Schweiger, the value shown includes financial planning services valued at $5,000 and $5,646 paid by Eversource representing the value in 2019 of a company-owned vehicle provided to Mr. Schweiger. None of the other Named Executive Officers received perquisites valued in the aggregate in excess of $10,000.

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(5) The amounts in the Adjusted SEC Total column reflect an adjustment to the total compensation reported in the column marked SEC Total. The Adjusted SEC Total subtracts the actuarial change in pension value disclosed in the column titled "Change in Pension Value and Non-Qualified Deferred Earnings" as further described in footnote 4 above in order to reflect compensation earned during the year by the executive without consideration of pension benefit impacts. The amounts in this column differ substantially from, and are not a substitute for, the amounts noted in the SEC Total.

GRANTS OF PLAN-BASED AWARDS DURING 2019

The Grants of Plan-Based Awards table below provides information on the range of potential payouts under all incentive plan awards during the fiscal year ended December 31, 2019. The table also discloses the underlying equity awards and the grant date for equity-based awards. Eversource has not granted any stock options since 2002.

												All Other Stock Awards: Number of  Shares of Stock or Units (#) (2)	Grant Date Fair Value of  Stock and Option Awards ($) (3)
		Estimated Future Payouts Under Non-Equity Incentive Plan Awards						Estimated Future Payouts Under Equity Incentive Plan Awards (1)
	Grant Date	Threshold ($)		Target ($)		Maximum ($)		Threshold ($)		Target (#)	Maximum (#)
Name
James J. Judge
Annual Incentive (4)	02/06/19	$	798,000	$	1,596,000	$	3,192,000	$	—	—	—	—	$	—
Long-Term Incentive (5)	02/06/19	—		—		—		—		46,249	92,498	46,249	6,676,043
Philip J. Lembo
Annual Incentive (4)	02/06/19	259,000		518,000		1,036,000		—		—	—	—	—
Long-Term Incentive (5)	02/06/19	—		—		—		—		10,103	20,206	10,103	1,458,368
Werner J. Schweiger
Annual Incentive (4)	02/06/19	272,000		544,000		1,088,000		—		—	—	—	—
Long-Term Incentive (5)	02/06/19	—		—		—		—		10,103	20,206	10,103	1,458,368
Gregory B. Butler
Annual Incentive (4)	02/06/19	211,500		423,000		846,000		—		—	—	—	—
Long-Term Incentive (5)	02/06/19	—		—		—		—		8,328	16,656	8,328	1,202,147
Joseph R. Nolan, Jr.
Annual Incentive (4)	02/06/19	193,500		387,000		774,000		—		—	—	—	—
Long-Term Incentive (5)	02/06/19	—		—		—		—		7,623	15,246	7,623	1,100,380

(1) Reflects the number of performance shares granted to each of the Named Executive Officers on February 6, 2019 under the 2019 - 2021 Long-Term Incentive Program. Performance shares were granted subject to a three-year Performance Period that ends on December 31, 2021. At the end of the Performance Period, Eversource common shares will be awarded based on actual performance results as a percentage of target, subject to reduction for applicable payroll withholding taxes. Holders of performance shares are eligible to receive dividend equivalent units on outstanding performance shares awarded to them to the same extent that dividends are declared and paid on Eversource common shares. Dividend equivalent units are accounted for as additional common shares that accrue and are distributed simultaneously with the number of common shares underlying the performance shares that are actually awarded. The Annual Incentive Program did not include an equity component.

(2) Reflects the number of RSUs granted to each of the Named Executive Officers on February 6, 2019 under the 2019 - 2021 Long-Term Incentive Program. RSUs vest in equal installments on February 6, 2020, 2021 and 2022. Eversource common shares will be distributed with respect to vested RSUs on a one-for-one basis following vesting, after reduction for applicable payroll withholding taxes. Holders of RSUs are eligible to receive dividend equivalent units on outstanding RSUs awarded to them to the same extent that dividends are declared and paid on Eversource common shares. Dividend equivalent units are accounted for as additional common shares that accrue and are distributed simultaneously with those common shares actually distributed in respect of the underlying RSUs.

(3) Reflects the grant date fair value, determined in accordance with FASB ASC Topic 718, of RSUs and performance shares granted to the Named Executive Officers on February 6, 2019 under the 2019 - 2021 Long-Term Incentive Program.

(4) The threshold payment under the Annual Incentive Program is 50% of target. The actual payments in 2020 for performance in 2019 are set forth in the Non-Equity Incentive Plan column of the Summary Compensation Table.

(5) Reflects the range of potential payouts, if any, pursuant to performance share awards under the 2019 - 2021 Long-Term Incentive Program, as described in the CD&A.

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OUTSTANDING EQUITY GRANTS AT DECEMBER 31, 2019

The following table sets forth RSU and performance share grants outstanding at the end of the fiscal year ended December 31, 2019 for each of the Named Executive Officers. There are no outstanding options.

	Stock Awards (1)
	Number of Shares or Units of Stock That Have Not Vested (#) (2)	Market Value of Shares or Units of Stock That Have Not Vested ($) (3)		Equity Incentive Plan Awards: Number of Unearned Shares, Units or Other Rights That Have Not Vested (#) (4)	Equity Incentive Plan Awards: Market or Payout Value of Unearned Shares, Units or Other Rights That Have Not Vested ($) (5)
Name
James J. Judge	99,770	$	8,487,360	152,329	$	12,958,613
Philip J. Lembo	22,150	1,884,309		34,344	2,921,677
Werner J. Schweiger	22,332	1,899,750		34,718	2,953,457
Gregory B. Butler	17,817	1,515,696		27,404	2,331,273
Joseph R. Nolan, Jr.	16,202	1,378,286		24,725	2,103,355

(1) Awards and market values of awards appearing in the table and the accompanying notes have been rounded to whole units.

(2) A total of 91,173 unvested RSUs will vest on February 6, 2020 (Mr. Judge: 50,777; Mr. Lembo: 11,447; Mr. Schweiger: 11,572; Mr. Butler: 9,135; and Mr. Nolan: 8,242). A total of 58,874 unvested RSUs will vest on February 8, 2021 (Mr. Judge: 33,153; Mr. Lembo: 7,242, Mr. Schweiger: 7,299; Mr. Butler: 5,830; and Mr. Nolan: 5,350). A total of 28,223 unvested RSUs will vest on February 7, 2022 (Mr. Judge: 15,840; Mr. Lembo: 3,460; Mr. Schweiger: 3,460; Mr. Butler: 2,852; and Mr. Nolan: 2,611).

(3) The market value of RSUs is determined by multiplying the number of RSUs by $85.07, the closing price of Eversource Energy common shares on December 31, 2019, the last trading day of the year.

(4) Reflects the target payout level for performance shares granted under the 2017 - 2019 Program, the 2018 - 2020 Program and the 2019 - 2021 Program.

The performance period for the 2017 - 2019 Program ended on December 31, 2019. Awards under that program are set forth in the CD&A under the "Results of the 2017 - 2019 Performance Share Program."

The performance share award for 2018 - 2020 Program and the 2019 - 2021 Program will be based on actual performance results as a percentage of target, subject to reduction for applicable payroll withholding taxes. As described more fully under "Performance Shares" in the CD&A and footnote (1) to the Grants of Plan-Based Awards table, performance shares will vest following a three-year performance period based on the extent to which the two performance conditions are achieved. Under the 2018 - 2020 Program, a total of 91,949 unearned performance shares (including accrued dividend equivalents) will vest based on the extent to which the two performance conditions described in the CD&A are achieved as of December 31, 2020, assuming achievement of these conditions at a target level of performance: Mr. Judge: 51,941; Mr. Lembo: 11,344; Mr. Schweiger: 11,517; Mr. Butler: 8,931; and Mr. Nolan: 8,216. Under the 2019 - 2021 Program, a total of 84,666 unearned performance shares (including accrued dividend equivalents) will vest based on the extent to which the two performance conditions described in the CD&A are achieved as of December 31, 2021. Assuming achievement of these conditions at a target level of performance, the amount of the awards would be as follows: Mr. Judge: 47,518; Mr. Lembo: 10,380; Mr. Schweiger: 10,380; Mr. Butler: 8,556; and Mr. Nolan: 7,832.

(5) The market value is determined by multiplying the number of performance shares in the adjacent column by $85.07, the closing price of Eversource Energy common shares on December 31, 2019, the last trading day of the year.

OPTION EXERCISES AND STOCK VESTED IN 2019

The following table reports amounts realized on equity compensation during the fiscal year ended December 31, 2019. The Stock Awards columns report the vesting of RSU and performance share grants to the Named Executive Officers in 2019.

	Stock Awards
	Number of Shares Acquired on Vesting (#) (1)	Value Realized on Vesting (2)
Name
James J. Judge	50,820	$	3,564,592
Philip J. Lembo	10,359	726,490
Werner J. Schweiger	24,432	1,714,758
Gregory B. Butler	17,028	1,195,032
Joseph R. Nolan, Jr.	11,866	832,598

(1) Includes RSUs and performance shares granted to the Named Executive Officers under the long-term incentive programs, including dividend reinvestment, as follows:

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Name	2016 Program	2017 Program	2018 Program	2019 Program
James J. Judge	16,816	17,152	16,852	—
Philip J. Lembo	2,584	4,095	3,680	—
Werner J. Schweiger	16,536	4,160	3,736	—
Gregory B. Butler	10,914	3,217	2,897	—
Joseph R. Nolan, Jr.	6,308	2,892	2,666	—

In all cases, the distribution of common shares is reduced by that number of shares valued in an amount sufficient to satisfy tax withholding obligations.

(2) Values realized on vesting of RSUs granted under the 2016 - 2018, 2017 - 2019 and 2018 - 2020 Programs were based on $70.10 per share, the closing price of Eversource Energy common shares on February 14, 2019. Values realized on vesting of performance shares granted under the 2016 - 2018 Program were based on $70.27 per share, the closing price of Eversource Energy common shares on February 20, 2019.

PENSION BENEFITS IN 2019

The Pension Benefits Table shows the estimated present value of accumulated retirement benefits payable to each Named Executive Officer upon retirement based on the assumptions described below. The table distinguishes between benefits available under the qualified pension program, the supplemental pension program, and any additional benefits available under contractual agreements. See the narrative above in the CD&A under the captions "Summary Compensation Table Versus Realized Pay Comparison - James J. Judge-Eversource CEO," "Other Benefits - Retirement Benefits" and "Contractual Agreements" for more detail on benefits under these plans and agreements.

The values shown in the Pension Benefits Table for Messrs. Judge, Lembo, Schweiger and Nolan were calculated as of December 31, 2019, based on benefit payments in the form of a lump sum. For Mr. Butler, a payment of benefits was assumed in the form of a contingent annuitant option. Such earned pension program benefit value could otherwise have changed because of the reduction in mortality factors and potentially rising interest rates.

The values shown in this Table for the Named Executive Officers were based on benefit payments on the actual ages or the earliest possible ages for retirement with unreduced benefits: Mr. Judge: age 60; Mr. Lembo: age 62; Mr. Schweiger: age 55; Mr. Butler: age 62; and Mr. Nolan: age 62.

In addition, benefits were determined under the qualified pension program using tax code limits in effect on December 31, 2019. For Messrs. Judge, Lembo, Schweiger and Nolan, the values shown reflect actual 2019 salary and annual incentives earned in 2018 but paid in 2019 (per applicable supplemental program rules). For Mr. Butler, the values shown reflect actual 2019 salary and annual incentives earned in 2019 but paid in 2020 (per applicable supplemental program rules).

Eversource determined the present value of benefits at retirement age using the discount rate within a range of 3.04% to 3.21% under ACS 715-30 pension accounting for the 2019 fiscal year end measurement as of December 31, 2019. This present value assumes no pre-retirement mortality, turnover or disability. However, for the postretirement period beginning at retirement age, the 2019 IRS lump sum mortality table was used for Messrs. Judge, Lembo, Schweiger and Nolan. The RP2014 Employee Table Projected Generationally with Scale MP2019 was used for Mr. Butler. This new mortality table (as published by the Society of Actuaries in 2014) and projection scale were used by the Eversource Pension Plan for year-end 2019 financial disclosure. Additional assumptions appear in the footnotes to the Annual Report on Form 10-K for the fiscal year ended December 31, 2019.

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Pension Benefits

		Number of Years Credited Service (#)	Present Value of Accumulated Benefit		During Last Fiscal Year
Name	Plan Name
James J. Judge	Retirement Plan	42.33	$	2,913,187	$	—
	Supplemental Plan	20.00	14,755,642		—
	Supplemental Plan	42.33	15,719,167		—
Philip J. Lembo	Retirement Plan	10.75	1,336,500		—
	Supplemental Plan	10.75	5,208,302		—
Werner J. Schweiger	Retirement Plan	17.83	599,033		—
	Supplemental Plan	17.83	2,512,305		—
	Supplemental Plan	17.00	8,131,823		—
Gregory B. Butler	Retirement Plan	23.00	1,425,654		—
	Supplemental Plan	23.00	5,674,956		—
	Target	23.00	4,558,338		—
Joseph R. Nolan, Jr.	Retirement Plan	20.33	1,017,250		—
	Supplemental Plan	20.33	3,477,146		—
	Supplemental Plan	20.00	5,474,992		—

NONQUALIFIED DEFERRED COMPENSATION IN 2019

The following table reports amounts contributed in 2019, together with aggregate earnings on contributions and withdrawals or distributions on contributions in 2019, under Eversource's deferred compensation program, along with aggregate balances on contributions. See the narrative above in the CD&A under the caption "Other Benefits - Deferred Compensation" for more detail on the non-qualified deferred compensation program.

	Executive Contributions in Last FY		Registrant Contributions in Last FY		Aggregate Earnings in in Last FY		Aggregate Withdrawals/ Distributions		Aggregate Balance at Last FYE (1)
Name
James J. Judge	$	—	$	—	$	2,066,717	$	—	$	8,110,416
Philip J. Lembo	—		—		306,112		—		1,615,523
Werner J. Schweiger	—		—		3,615,557		—		19,806,849
Gregory B. Butler	—		—		6,309		—		27,503
Joseph R. Nolan, Jr.	—		—		1,677,324		—		6,693,619

(1) Includes the total market value of deferred compensation program balances at December 31, 2019, plus the value of vested RSUs or other awards for which the distribution of common shares is currently deferred, based on $85.07, the closing price of Eversource common shares on December 31, 2019, the last trading day of the year. The aggregate balances reflect a significant level of earnings on previously earned and deferred compensation.

POTENTIAL PAYMENTS UPON TERMINATION OR CHANGE IN CONTROL

The discussion and tables below show compensation payable to each Named Executive Officer who is still an employee of Eversource, in the event of: (i) voluntary termination; (ii) involuntary not-for-cause termination; (iii) termination in the event of death or disability; and (iv) termination following a change in control. No amounts are payable in the event of a termination for cause. The amounts shown assume that each termination was effective as of December 31, 2019, the last business day of the fiscal year.

Generally, a "change in control" means a change in ownership or control effected through (i) the acquisition of 30 percent or more of the combined voting power of common shares or other voting securities (20 percent for Mr. Butler, excluding certain defined transactions); (ii) the acquisition of more than 50 percent of Eversource common shares, excluding certain defined transactions (for Messrs. Judge, Lembo, Schweiger and Nolan); (iii) a change in the majority of the Eversource Board of Trustees, unless approved by a majority of the incumbent Trustees; (iv) certain reorganizations, mergers or consolidations where substantially all of the persons who were the beneficial owners of the outstanding common shares immediately prior to such business combination do not beneficially own more than 50 percent of the voting power of the resulting business entity (excluding in certain cases defined transactions); and (v) complete liquidation or dissolution of Eversource, or a sale or disposition of all or substantially all of the assets of Eversource other than, for Mr. Butler, to an entity with respect to which following completion of the transaction more than 50 percent of common shares or other voting securities is then owned by all or substantially all of the persons who were the beneficial owners of common shares and other voting securities immediately prior to such transaction.

In the event of a change in control, the Named Executive Officers are generally entitled to receive compensation and benefits following either involuntary termination of employment without "cause" or voluntary termination of employment for "good reason" within the applicable period (generally two years following a change in control). The Committee believes that termination for good reason is conceptually the same as termination "without cause" and, in the absence of this provision, potential acquirers would have an incentive to constructively terminate executives to avoid paying severance. Termination for "cause" generally means termination due to a felony or certain other convictions; fraud, embezzlement, or theft in the course of employment; intentional, wrongful damage to Eversource property; gross misconduct or gross negligence in the course of employment or gross neglect of duties harmful to Eversource; or a material breach of obligations under the

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agreement. "Good reason" for termination generally exists after assignment of duties inconsistent with executive's position, a material reduction in compensation or benefits, a transfer more than 50 miles from the executive's pre-change in control principal business location (or for Messrs. Judge, Lembo, Schweiger and Nolan, an involuntary transfer outside the Greater Boston Metropolitan Area), or requiring business travel to a substantially greater extent than required prior to the change in control.

The summaries above do not purport to be complete and are qualified in their entirety by the actual terms and provisions of the agreements and plans, copies of which have been filed as exhibits to this Annual Report on Form 10-K for the year ended December 31, 2019.

Payments Upon Termination

Regardless of the manner in which the employment of a Named Executive Officer terminates, the executive is entitled to receive certain amounts earned during the executive's term of employment. Such amounts include:

• Vested RSUs and certain other vested awards;

• Amounts contributed and any vested matching contributions under the deferred compensation program;

• Pay for unused vacation; and

• Amounts accrued and vested under the pension/supplemental and 401k programs (except in the event of a termination for cause under the supplemental program).

The following table describes additional compensation payable to the Named Executive Officers in the event of voluntary termination, involuntary termination not for cause, termination in the event of death or disability and termination following a change in control. No benefits are provided in the event of termination for cause. See the section above captioned "Pension Benefits in 2019" for information about the pension program, supplemental program and other benefits, and the section captioned "Nonqualified Deferred Compensation in 2019."

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POST-EMPLOYMENT COMPENSATION PAYMENTS UPON TERMINATION

Name	Type of Payments	Voluntary Termination		Involuntary Termination Not for Cause		Termination Upon Death or Disability		Termination Following a Change in Control
James J. Judge	Annual Incentives (1)	$	—	$	—	$	—	$	1,596,000
	Performance Shares (2)	8,792,108		8,792,108		8,792,108		12,958,613
	RSUs (3)	3,974,005		3,974,005		3,974,005		8,487,360
	Special Retirement Benefit (4)	—		—		—		6,997,917
	Health and Welfare Benefits (5)	—		—		—		96,289
	Perquisites (6)	—		—		—		15,000
	Excise Tax and Gross-ups (7)	—		—		—		10,506,837
	Separation Payment for Liquidated Damages (8)	—		—		—		11,280,000
	Total	$	12,766,113	$	12,766,113	$	12,766,113	$	51,938,016
Philip J. Lembo	Annual Incentives (1)	$	—	$	—	$	—	$	518,000
	Performance Shares (2)	2,011,593		2,011,593		2,011,593		2,921,677
	RSUs (3)	895,955		895,955		895,955		1,884,309
	Special Retirement Benefit (4)	—		—		—		2,345,917
	Health and Welfare Benefits (5)	—		—		—		42,810
	Perquisites (6)	—		—		—		10,000
	Separation Payment for Liquidated Damages (8)	—		—		—		2,910,000
	Total	$	2,907,548	$	2,907,548	$	2,907,548	$	10,632,713
Werner J. Schweiger	Annual Incentives (1)	$	—	$	—	$	—	$	544,000
	Performance Shares (2)	2,038,514		2,038,514		2,038,514		2,953,457
	RSUs (3)	905,673		905,673		905,673		1,899,750
	Special Retirement Benefit (4)	—		—		—		6,046,821
	Health and Welfare Benefits (5)	—		—		—		80,083
	Perquisites (6)	—		—		—		15,000
	Separation Payment for Liquidated Damages (8)	—		—		—		1,954,855
	Total	$	2,944,187	$	2,944,187	$	2,944,187	$	13,493,966
Gregory B. Butler	Annual Incentives (1)	$	—	$	—	$	—	$	423,000
	Performance Shares (2)	1,592,867		1,592,867		1,592,867		2,331,273
	RSUs (3)	714,953		714,953		714,953		1,515,696
	Special Retirement Benefit (4)	¯		5,572,153		¯		5,572,153
	Health and Welfare Benefits (5)	¯		22,404		¯		33,607
	Perquisites (6)	¯		10,000		¯		15,000
	Excise Tax and Gross-Ups (7)	¯		2,818,443		¯		2,818,443
	Separation Payment for Liquidated Damages (8)	¯		1,073,000		¯		1,073,000
	Separation Payment for Non-Compete Agreement (9)	¯		1,073,000		¯		2,146,000
	Total	$	2,307,820	$	12,876,820	$	2,307,820	$	15,928,172
Joseph R. Nolan, Jr.	Annual Incentives (1)	$	—	$	—	$	—	$	387,000
	Performance Shares (2)	1,426,297		1,426,297		1,426,297		2,103,355
	RSUs (3)	645,029		645,029		645,029		1,378,286
	Special Retirement Benefit (4)	—		—		—		3,571,439
	Health and Welfare Benefits (5)	—		—		—		87,254
	Perquisites (6)	—		—		—		15,000
	Excise Tax and Gross-ups (7)	—		—		—		2,774,844
	Separation Payment for Liquidated Damages (8)	—		—		—		3,945,000
	Total	$	2,071,326	$	2,071,326	$	2,071,326	$	14,262,178

(1) For Termination Following a Change in Control: Represents target 2019 annual incentive awards as described in the Grants of Plan Based Awards Table.

(2) For Voluntary Termination and Involuntary Termination Not for Cause and Termination Upon Death or Disability: Represents 100 percent of the performance share awards under the 2017 - 2019 Long-Term Incentive Program, 67 percent of the performance share awards under the 2018 - 2020 Long-Term Incentive Program and 33 percent of the performance share awards under the 2019 - 2021 Long-Term Incentive Program. For all of the Named Executive Officers, the values were calculated by multiplying the number of RSUs by $85.07, the closing price of Eversource common shares on December 31, 2019, the last trading day of the year. For Termination Following a Change in Control: Represents 100 percent of the performance share awards under each of the three programs noted in the previous two sentences.

(3) For Voluntary Termination and Involuntary Termination Not for Cause and Termination Upon Death or Disability, represents values of RSUs granted under long-term incentive programs that, at year-end 2019, were unvested under applicable vesting schedules. Under these programs, RSUs vest pro rata based on credited service years and age at termination, and time worked during the vesting period. For all, the values were calculated by multiplying the number of RSUs by $85.07, the closing price of Eversource common shares on December 31, 2019, the last trading day of the year.

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For Termination Following a Change in Control: Represents values of all RSUs granted under long-term incentive programs that, at year-end 2019, were unvested under applicable vesting schedules, all of which vest in full.

(4) The amount noted in the Involuntary Termination, Not for Cause column, represents for Mr. Butler actuarial present values at year-end 2019 of amounts payable (two years of service) solely under an employment agreement upon termination, which are in addition to amounts due under the pension plan. For Termination Following a Change in Control: represents actuarial present values at year-end 2019 of amounts payable solely under employment agreements upon termination (which are in addition to amounts due under the pension program). For Messrs. Judge, Schweiger, Butler and Nolan, pension benefits were calculated by adding three years of service (two years for Mr. Lembo). A lump sum of this benefit value is payable to Messrs. Judge, Lembo and Schweiger. Pension amounts shown in the table are present values at year-end 2019 of benefits payable upon termination as described with respect to the Pension Benefits Table above.

(5) The amount noted in the Involuntary Termination, Not for Cause column, represents for Mr. Butler the value of two years' employer contributions toward active health, long-term disability, and life insurance benefits, plus a payment to offset any taxes thereon. For Termination Following a Change in Control: represents estimated cost to Eversource at year-end 2019 (estimated by consultants) of providing post-employment health and welfare benefits beyond those available to non-executives upon involuntary termination. The amounts shown in the table for Messrs. Judge, Schweiger and Nolan represent the value of three years (two years for Mr. Lembo) continued health and welfare plan participation. The amounts shown in the table for Mr. Butler represent the value of three years' employer contributions toward active health, long-term disability, and life insurance benefits, plus a payment to offset any taxes on the value of these benefits, less the value of one year of retiree health coverage at retiree rates.

(6) The amount noted in the Involuntary Termination, Not for Cause column, represents for Mr. Butler the cost of reimbursing Mr. Butler for two years financial planning and tax preparation fees. For Termination Following a Change in Control, represents the cost to Eversource of reimbursing for financial planning and tax preparation fees for three years (two years for Mr. Lembo).

(7) For Termination Following a Change in Control, represents payments made to offset costs associated with certain excise taxes under Section 280G of the Internal Revenue Code. Executives may be subject to certain excise taxes under Section 280G if they receive payments and benefits related to a Termination Following a Change in Control that exceed specified Internal Revenue Service limits. Contractual agreements with the above executives provide for a grossed-up reimbursement of these excise taxes. The amounts in the table are based on the Section 280G excise tax rate of 20 percent, the statutory federal income tax withholding rate of 35 percent, the applicable state income tax rate, and the Medicare tax rate of 1.45 percent.

(8) For Involuntary Termination, Not for Cause, represents for Mr. Butler a severance payment (two-times the sum of base salary plus relevant annual incentive award) in addition to any non-compete agreement payment described above. For Termination Following a Change in Control, represents severance payments in addition to any non-compete agreement payments described in the prior note. For Messrs. Judge, Schweiger and Nolan, this payment equals three-times the sum of base salary plus relevant annual incentive award (two-times the sum for Messrs. Lembo and Butler). These payments do not replace, offset or otherwise affect the calculation or payment of the annual incentive awards.

(9) For Involuntary Termination, Not for Cause and Termination Following a Change in Control, represents payments made under agreements or Eversource programs to Mr. Butler as consideration for agreement not to compete with Eversource following termination of employment, equal to the sum of base salary plus relevant annual incentive award. These payments do not replace, offset or otherwise affect the calculation or payment of the annual incentive awards.

PAY RATIO

Eversource's CEO to median employee pay ratio is calculated pursuant to the requirements of Item 402(u) of Regulation S-K. Eversource identified the median employee by reviewing the 2019 total cash compensation of all full-time employees, excluding Eversource's CEO, who were employed by Eversource and its subsidiaries on December 31, 2019. In Eversource's assessment of median employee compensation, pay was annualized for those employees who commenced work during 2019. Otherwise, no assumptions, adjustments, or estimates were made with respect to total cash compensation, and the compensation for any full-time employees who were not employed Eversource at the end of 2019 was not annualized. Eversource believes the use of total cash compensation for all employees is a consistently applied compensation measure, as Eversource does not widely distribute annual equity awards to employees.

After identifying the median employee based on total cash compensation, Eversource calculated the annual total compensation for such employee using the same methodology it uses for its Named Executive Officers as set forth in the 2019 Summary Compensation Table.

Mr. Judge had 2019 annual total compensation of $19,806,088, as reflected in the Summary Compensation Table. Eversource's median employee's annual total compensation for 2019 was $133,899. Eversource's 2019 CEO to median employee pay ratio is 148 to 1.

153

Item 12.    Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

Eversource Energy

In addition to the information below under "Securities Authorized for Issuance Under Equity Compensation Plans," incorporated herein by reference is the information contained in the sections "Common Share Ownership of Certain Beneficial Owners" and "Common Share Ownership of Trustees and Management" of Eversource Energy's definitive proxy statement for solicitation of proxies, expected to be filed with the SEC on or about March 26, 2020.

NSTAR ELECTRIC and PSNH

Certain information required by this Item 12 has been omitted for NSTAR Electric and PSNH pursuant to Instruction I(2)(c) to Form 10-K, Omission of Information by Certain Wholly-Owned Subsidiaries.

CL&P

COMMON SHARE OWNERSHIP OF DIRECTORS AND MANAGEMENT

Eversource Energy owns 100 percent of the outstanding common stock of CL&P.  The table below shows the number of Eversource Energy common shares beneficially owned as of February 18, 2020, by each of CL&P's directors and each Named Executive Officer of CL&P, as well as the number of Eversource Energy common shares beneficially owned by all of CL&P's directors and executive officers as a group.  The table also includes information about restricted share units and deferred shares credited to the accounts of CL&P's directors and executive officers under certain compensation and benefit plans.  No equity securities of CL&P are owned by any of the Trustees, directors or executive officers of Eversource Energy or CL&P.  The address for the shareholders listed below is c/o Eversource Energy, Prudential Center, 800 Boylston Street, Boston, Massachusetts 02199 for Messrs. Judge, Lembo, Nolan and Schweiger; c/o Eversource Energy, 56 Prospect Street, Hartford, Connecticut 06103-2818 for Mr. Butler.

Name of Beneficial Owner	Amount and Nature of Beneficial Ownership (1)(2)(3)		Percent of Class
James J. Judge, Chairman of CL&P	312,760		*
Philip J. Lembo, Executive Vice President and Chief Financial Officer, Director of CL&P	63,017	(4)	*
Werner J. Schweiger, Chief Executive Officer, Director of CL&P	253,158	(5)	*
Gregory B. Butler, Executive Vice President and General Counsel, Director of CL&P	95,143		*
Joseph R. Nolan, Jr., Executive Vice President-Strategy, Customer and Corporate Relations of Eversource Service	111,473		*
All directors and executive officers as a group (7 persons)	912,459	(6)	*

* Less than 1 percent of Eversource Energy common shares outstanding.

1. The persons named in the table have sole voting and investment power with respect to all shares beneficially owned by each of them, except as noted below.

2. Includes restricted share units, deferred restricted share units and/or deferred shares, including dividend equivalents, as to which none of the individuals has voting or investment power, and phantom shares held by executive officers who participate in a deferred compensation plan as follows: Mr. Judge: 178,116 shares; Mr. Lembo: 19,337; Mr. Schweiger: 159,819 shares; Mr. Butler: 15,495 shares; and Mr. Nolan: 74,763 shares.

3. Includes shares held as units in the 401(k) Plan invested in the Eversource Energy Common Shares Fund over which the holder has sole voting and investment power as follows: Mr. Judge: 27,135 shares; Mr. Lembo: 122 shares; Mr. Schweiger: 691 shares; Mr. Butler: 6,291 shares; and Mr. Nolan: 19,366 shares.

4. Includes 542 shares held by Mr. Lembo in a custodial account and 125 shares held in a charitable trust over which Mr. Lembo has sole voting and investment power.

5. Includes 4,596 shares held in a trust of which Mr. Schweiger is the trustee and beneficiary; 437 shares in a trust of which Mr. Schweiger’s spouse is the trustee and beneficiary; and 433 shares held by Mr. Schweiger’s spouse in a custodial account.

6. Includes 468,709 unissued shares (see Note 2) and 58,471 shares held as units in the 401(k) Plan (see Note 3).

154

SECURITIES AUTHORIZED FOR ISSUANCE UNDER EQUITY COMPENSATION PLANS

The following table sets forth the number of Eversource Energy common shares issuable under Eversource Energy equity compensation plans, as well as their weighted exercise price, as of December 31, 2019, in accordance with the rules of the SEC:

Plan Category	Number of securities to be issued upon exercise of outstanding options, warrants and rights (1)	Weighted-average exercise price of outstanding options, warrants and rights (2)	Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (1))
Equity compensation plans approved by security holders	1,261,070	$—	3,302,526
Equity compensation plans not approved by security holders (3)	—	—	—
Total	1,261,070	$—	3,302,526

(1) Includes 774,163 common shares for distribution in respect of restricted share units, and 486,907 performance shares issuable at target, all pursuant to the terms of our Incentive Plan.

(2) The weighted-average exercise price does not take into account restricted share units or performance shares, which have no exercise price.

(3) Securities set forth in this table are authorized for issuance under compensation plans that have been approved by shareholders of Eversource Energy or the former shareholders of NSTAR.

Item 13.    Certain Relationships and Related Transactions, and Director Independence

Eversource Energy

Incorporated herein by reference is the information contained in the sections captioned "Trustee Independence" and "Related Person Transactions" of Eversource Energy's definitive proxy statement for solicitation of proxies, expected to be filed with the SEC on or about March 26, 2020.

NSTAR ELECTRIC and PSNH

Certain information required by this Item 13 has been omitted for NSTAR Electric and PSNH pursuant to Instruction I(2)(c) to Form 10-K, Omission of Information by Certain Wholly-Owned Subsidiaries.

CL&P

Eversource Energy's Code of Ethics for Senior Financial Officers applies to the Senior Financial Officers (Chief Executive Officer, Chief Financial Officer and Controller) of Eversource Energy, CL&P and certain other Eversource Energy subsidiaries.  Under the Code, one's position as a Senior Financial Officer in the company may not be used to improperly benefit such officer or his or her family or friends.  Under the Code, specific activities that may be considered conflicts of interest include, but are not limited to, directly or indirectly acquiring or retaining a significant financial interest in an organization that is a customer, vendor or competitor, or that seeks to do business with the company; serving, without proper safeguards, as an officer or director of, or working or rendering services for an organization that is a customer, vendor or competitor, or that seeks to do business with the company. Waivers of the provisions of the Code of Ethics for Trustees, executive officers or directors must be approved by Eversource Energy's Board of Trustees.  Any such waivers will be disclosed pursuant to legal requirements.

Eversource Energy's Code of Conduct, which applies to all Trustees, directors, officers and employees of Eversource Energy and its subsidiaries, including CL&P, contains a Conflict of Interest Policy that requires all such individuals to disclose any potential conflicts of interest.  Such individuals are expected to discuss their particular situations with management to ensure appropriate steps are in place to avoid a conflict of interest.  All disclosures must be reviewed and approved by management to ensure a particular situation does not adversely impact the individual's primary job and role.

Eversource Energy's Related Persons Transactions Policy is administered by the Corporate Governance Committee of Eversource Energy's Board of Trustees.  The Policy generally defines a "Related Persons Transaction" as any transaction or series of transactions in which (i) Eversource Energy or a subsidiary is a participant, (ii) the aggregate amount involved exceeds $120,000 and (iii) any "Related Persons" has a direct or indirect material interest.  A "Related Persons" is defined as any Trustee or nominee for Trustee, any executive officer, any shareholder owning more than 5 percent of Eversource Energy's total outstanding shares, and any immediate family member of any such person.  Management submits to the Corporate Governance Committee for consideration any Related Persons Transaction into which Eversource Energy or a subsidiary proposes to enter.  The Corporate Governance Committee recommends to the Eversource Energy Board of Trustees for approval only those transactions that are in Eversource Energy's best interests.  If management causes the company to enter into a Related Persons Transaction prior to approval by the Corporate Governance Committee, the transaction will be subject to ratification by the Eversource Energy Board of Trustees.  If the Eversource Energy Board of Trustees determines not to ratify the transaction, then management will make all reasonable efforts to cancel or annul such transaction.

The directors of CL&P are employees of CL&P and/or other subsidiaries of Eversource Energy, and thus are not considered independent.

155

Item 14.    Principal Accountant Fees and Services

Eversource Energy

Incorporated herein by reference is the information contained in the section "Relationship with Independent Auditors" of Eversource Energy's definitive proxy statement for solicitation of proxies, expected to be filed with the SEC on or about March 26, 2020.

CL&P, NSTAR ELECTRIC and PSNH

Pre-Approval of Services Provided by Principal Auditors

None of CL&P, NSTAR Electric and PSNH is subject to the audit committee requirements of the SEC, the national securities exchanges or the national securities associations.  CL&P, NSTAR Electric and PSNH obtain audit services from the independent auditor engaged by the Audit Committee of Eversource Energy's Board of Trustees.  Eversource Energy's Audit Committee has established policies and procedures regarding the pre-approval of services provided by the principal auditors.  Those policies and procedures delegate pre-approval of services to the Eversource Energy Audit Committee Chair provided that such offices are held by Trustees who are "independent" within the meaning of the Sarbanes-Oxley Act of 2002 and that all such pre-approvals are presented to the Eversource Energy Audit Committee at the next regularly scheduled meeting of the Committee.

The following relates to fees and services for the entire Eversource Energy system, including Eversource Energy, CL&P, NSTAR Electric and PSNH.

Fees Billed By Principal Independent Registered Public Accounting Firm

The aggregate fees, including out of pocket expense reimbursements, billed to the Company and its subsidiaries by Deloitte & Touche LLP, the member firms of Deloitte Touche Tohmatsu, and their respective affiliates (collectively, the Deloitte Entities), for the years ended December 31, 2019 and 2018 totaled $5,641,614 and $5,076,922, respectively. In addition, affiliates of Deloitte & Touche LLP, as noted below, provide other accounting services to the Company.  Fees consisted of the following:

1.    Audit Fees

The aggregate fees billed to the Company and its subsidiaries by Deloitte & Touche LLP for audit services rendered for the years ended December 31, 2019 and 2018 totaled $4,743,400 and $4,464,500, respectively.  The audit fees were incurred for audits of consolidated financial statements of Eversource Energy and its subsidiaries, reviews of financial statements included in the Combined Quarterly Reports on Form 10-Q of Eversource Energy and its subsidiaries, and other costs.  The fees also included audits of internal controls over financial reporting as of December 31, 2019 and 2018.  

2.    Audit-Related Fees

The aggregate fees billed to the Company and its subsidiaries by the Deloitte Entities for audit-related services rendered for the years ended December 31, 2019 and 2018 totaled $851,300 and $547,500, respectively.  The audit-related fees were incurred for procedures performed in the ordinary course of business in support of certain regulatory filings, comfort letters, consents, and other costs related to registration statements and financings.

3.    Tax Fees

The aggregate fees billed to the Company and its subsidiaries by the Deloitte Entities for tax services rendered for the years ended December 31, 2019 and 2018 totaled $45,000 and $7,500, respectively. The tax service fees were incurred for procedures performed in the ordinary course of business in support of certain federal rulings in 2019 and certain employee benefit plan federal filings in 2018.

4.    All Other Fees

The aggregate fees billed to the Company and its subsidiaries by the Deloitte Entities for services, other than the services described above, for the years ended December 31, 2019 and 2018 totaled $1,914 and $57,422, respectively.  These fees were for a license for access to an accounting standards research tool in 2019 and 2018, and the review of benefit payment calculations in 2018.

The Audit Committee pre-approves all auditing services and permitted audit-related or other services (including the fees and terms thereof) to be performed for us by our independent registered public accounting firm, subject to the de minimis exceptions for non-audit services described in Section 10A(i)(1)(B) of the Securities Exchange Act of 1934, which are approved by the Audit Committee prior to the completion of the audit. The Audit Committee may form and delegate its authority to subcommittees consisting of one or more members when appropriate, including the authority to grant pre-approvals of audit and permitted non-audit services, provided that decisions of such subcommittee to grant pre-approvals are presented to the full Audit Committee at its next scheduled meeting.  During 2019, all services described above were pre-approved by the Audit Committee or its Chair.  

156

The Audit Committee has considered whether the provision by the Deloitte Entities of the non-audit services described above was allowed under Rule 2-01(c)(4) of Regulation S-X and was compatible with maintaining the independence of the registered public accountants and has concluded that the Deloitte Entities were and are independent of us in all respects.

157

PART IV

Item 15.    Exhibits and Financial Statement Schedules

(a)	1.	Financial Statements:
			The financial statements filed as part of this Annual Report on Form 10-K are set forth under Item 8, "Financial Statements and Supplementary Data."
	2.	Schedules
		I.	Financial Information of Registrant:
			Eversource Energy (Parent) Balance Sheets as of December 31, 2019 and 2018	S-1
			Eversource Energy (Parent) Statements of Income for the Years Ended December 31, 2019, 2018 and 2017	S-2
			Eversource Energy (Parent) Statements of Comprehensive Income for the Years Ended December 31, 2019, 2018 and 2017	S-2
			Eversource Energy (Parent) Statements of Cash Flows for the Years Ended December 31, 2019, 2018 and 2017	S-3
		II.	Valuation and Qualifying Accounts and Reserves for Eversource, CL&P, NSTAR Electric and PSNH for 2019, 2018 and 2017	S-4
			All other schedules of the companies for which inclusion is required in the applicable regulations of the SEC are permitted to be omitted under the related instructions or are not applicable, and therefore have been omitted.
	3.		Exhibit Index	E-1

Item 16.     Form 10-K Summary

Not applicable.

158

SCHEDULE I

EVERSOURCE ENERGY (PARENT)

FINANCIAL INFORMATION OF REGISTRANT

BALANCE SHEETS

AS OF DECEMBER 31, 2019 AND 2018

(Thousands of Dollars)

	2019			2018
ASSETS
Current Assets:
Cash	$	1,469		$	591
Accounts Receivable from Subsidiaries	25,070			32,175
Notes Receivable from Subsidiaries	1,376,000			991,400
Prepayments and Other Current Assets	33,546			26,861
Total Current Assets	1,436,085			1,051,027
Deferred Debits and Other Assets:
Investments in Subsidiary Companies, at Equity	13,162,337			12,009,659
Notes Receivable from Subsidiaries	157,000			323,500
Accumulated Deferred Income Taxes	27,578			40,454
Goodwill	3,231,811			3,231,811
Other Long-Term Assets	92,394			73,669
Total Deferred Debits and Other Assets	16,671,120			15,679,093
Total Assets	$	18,107,205		$	16,730,120
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	878,584		$	631,500
Long-Term Debt - Current Portion	23,933			378,883
Accounts Payable to Subsidiaries	4,333			8,432
Other Current Liabilities	62,385			57,877
Total Current Liabilities	969,235			1,076,692
Deferred Credits and Other Liabilities	149,637			134,614
Long-Term Debt	4,358,339			4,031,997
Common Shareholders' Equity:
Common Shares	1,729,292			1,669,392
Capital Surplus, Paid in	7,087,768			6,241,222
Retained Earnings	4,177,048			3,953,974
Accumulated Other Comprehensive Loss	(65,059		)	(60,000		)
Treasury Stock	(299,055		)	(317,771		)
Common Shareholders' Equity	12,629,994			11,486,817
Total Liabilities and Capitalization	$	18,107,205		$	16,730,120

See the Combined Notes to Financial Statements in this Annual Report on Form 10-K for a description of significant accounting matters related to Eversource parent, including Eversource common shares information as described in Note 19, "Common Shares," material obligations and guarantees as described in Note 13, "Commitments and Contingencies," and debt agreements as described in Note 8, "Short-Term Debt," and Note 9, "Long-Term Debt."

S-1

SCHEDULE I

EVERSOURCE ENERGY (PARENT)

FINANCIAL INFORMATION OF REGISTRANT

STATEMENTS OF INCOME

FOR THE YEARS ENDED DECEMBER 31, 2019, 2018 AND 2017

(Thousands of Dollars, Except Share Information)

	2019			2018			2017
Operating Revenues	$	—		$	—		$	—
Operating Expenses:
Other	50,100			(6,552		)	(32,189		)
Operating (Loss)/Income	(50,100		)	6,552			32,189
Interest Expense	163,937			123,638			80,700
Other Income, Net:
Equity in Earnings of Subsidiaries	1,001,526			1,049,748			993,063
Other, Net	68,137			47,581			23,339
Other Income, Net	1,069,663			1,097,329			1,016,402
Income Before Income Tax Benefit	855,626			980,243			967,891
Income Tax Benefit	(53,427		)	(52,757		)	(20,105		)
Net Income	$	909,053		$	1,033,000		$	987,996
Basic Earnings per Common Share	$	2.83		$	3.25		$	3.11
Diluted Earnings per Common Share	$	2.81		$	3.25		$	3.11
Weighted Average Common Shares Outstanding:
Basic	321,416,086			317,370,369			317,411,097
Diluted	322,941,636			317,993,934			318,031,580

STATEMENTS OF COMPREHENSIVE INCOME

	2019			2018			2017
Net Income	$	909,053		$	1,033,000		$	987,996
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	1,393			1,756			1,974
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,166			(547		)	(350		)
Change in Funded Status of Pension, SERP and PBOP Benefit Plans	(7,618		)	5,194			(2,745		)
Other Comprehensive (Loss)/Income, Net of Tax	(5,059		)	6,403			(1,121		)
Comprehensive Income	$	903,994		$	1,039,403		$	986,875

See the Combined Notes to Financial Statements in this Annual Report on Form 10-K for a description of significant accounting matters related to Eversource parent, including Eversource common shares information as described in Note 19, "Common Shares," material obligations and guarantees as described in Note 13, "Commitments and Contingencies," and debt agreements as described in Note 8, "Short-Term Debt," and Note 9, "Long-Term Debt."

S-2

SCHEDULE I

EVERSOURCE ENERGY (PARENT)

FINANCIAL INFORMATION OF REGISTRANT

STATEMENTS OF CASH FLOWS

FOR THE YEARS ENDED DECEMBER 31, 2019, 2018 and 2017

(Thousands of Dollars)

	2019			2018			2017
Operating Activities:
Net Income	$	909,053		$	1,033,000		$	987,996
Adjustments to Reconcile Net Income to Net Cash
Flows Provided by Operating Activities:
Equity in Earnings of Subsidiaries	(1,001,526		)	(1,049,748		)	(993,063		)
Cash Dividends Received from Subsidiaries	883,000			569,500			753,300
Deferred Income Taxes	13,382			20,032			37,867
Other	19,584			(31,093		)	(36,052		)
Changes in Current Assets and Liabilities:
Accounts Receivables from Subsidiaries	7,105			(28,716		)	29,405
Taxes Receivable/Accrued, Net	(605		)	(20,207		)	1,555
Accounts Payable to Subsidiaries	(4,099		)	(9,817		)	9,763
Other Current Assets and Liabilities, Net	(2,503		)	2,553			7,536
Net Cash Flows Provided by Operating Activities	823,391			485,504			798,307
Investing Activities:
Capital Contributions to Subsidiaries	(1,039,000		)	(955,700		)	(1,156,731		)
Return of Capital from Subsidiary	—			530,000			—
Increase in Notes Receivable from Subsidiaries	(218,100		)	(158,210		)	(192,100		)
Other Investing Activities	(1,799		)	(1,149		)	1,484
Net Cash Flows Used in Investing Activities	(1,258,899		)	(585,059		)	(1,347,347		)
Financing Activities:
Issuance of Common Shares, Net of Issuance Costs	852,254			—			—
Cash Dividends on Common Shares	(663,239		)	(640,110		)	(602,083		)
Issuance of Long-Term Debt	—			1,550,000			1,200,000
Retirement of Long-Term Debt	(350,000		)	(450,000		)	—
Increase/(Decrease) in Notes Payable	593,370			(347,810		)	(42,690		)
Other Financing Activities	4,001			(12,455		)	(5,759		)
Net Cash Flows Provided by Financing Activities	436,386			99,625			549,468
Net Increase in Cash	878			70			428
Cash - Beginning of Year	591			521			93
Cash - End of Year	$	1,469		$	591		$	521
Supplemental Cash Flow Information:
Cash Paid/(Received) During the Year for:
Interest	$	161,323		$	118,533		$	73,868
Income Taxes	$	(63,227	)	$	(30,239	)	$	(59,526	)

See the Combined Notes to Financial Statements in this Annual Report on Form 10-K for a description of significant accounting matters related to Eversource parent, including Eversource common shares information as described in Note 19, "Common Shares," material obligations and guarantees as described in Note 13, "Commitments and Contingencies," and debt agreements as described in Note 8, "Short-Term Debt," and Note 9, "Long-Term Debt."

S-3

SCHEDULE II

EVERSOURCE ENERGY AND SUBSIDIARIES

VALUATION AND QUALIFYING ACCOUNTS AND RESERVES

FOR THE YEARS ENDED DECEMBER 31, 2019, 2018 AND 2017

(Thousands of Dollars)

Column A		Column B		Column C				Column D		Column E
				Additions
				(1)		(2)
				Charged		Charged to
		Balance as		to Costs		Other		Deductions -		Balance
		of Beginning		and		Accounts -		Describe		as of
Description:		of Year		Expenses		Describe (a)		(b)		End of Year
Eversource:
Reserves Deducted from Assets -
Reserves for Uncollectible Accounts:
	2019	$	212,723	$	63,446	$	57,223	$	108,571	$	224,821
	2018	195,708		61,337		48,671		92,993		212,723
	2017	200,630		44,665		47,630		97,217		195,708
CL&P:
Reserves Deducted from Assets -
Reserves for Uncollectible Accounts:
	2019	$	88,034	$	15,947	$	38,935	$	45,568	$	97,348
	2018	78,872		15,831		29,524		36,193		88,034
	2017	86,391		5,312		25,533		38,364		78,872
NSTAR Electric:
Reserves Deducted from Assets -
Reserves for Uncollectible Accounts:
	2019	$	74,516	$	25,079	$	12,556	$	36,745	$	75,406
	2018	69,666		22,279		14,971		32,400		74,516
	2017	70,284		21,252		14,273		36,143		69,666
PSNH:
Reserves Deducted from Assets -
Reserves for Uncollectible Accounts:
	2019	$	11,065	$	6,726	$	872	$	8,166	$	10,497
	2018	10,481		6,383		953		6,752		11,065
	2017	9,941		6,917		464		6,841		10,481

(a) Amounts relate to uncollectible accounts receivables reserved for that are not charged to bad debt expense.  The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively.  The DPU allows NSTAR Electric and NSTAR Gas to recover in rates, amounts associated with certain uncollectible hardship accounts receivable. 

(b) Amounts written off, net of recoveries.  

S-4

EXHIBIT INDEX

Each document described below is incorporated by reference by the registrant(s) listed to the files identified, unless designated with a (*), which exhibits are filed herewith.  Management contracts and compensation plans or arrangements are designated with a (+).

Exhibit

Number        Description

3.    Articles of Incorporation and By-Laws

(A)    Eversource Energy

3.1 Declaration of Trust of Eversource Energy, as amended through May 3, 2017 (Exhibit 3.1, Eversource Form 10-Q filed on May 5, 2017)

(B)    The Connecticut Light and Power Company

3.1 Amended and Restated Certificate of Incorporation (Exhibit 3(i), CL&P Current Report on Form 8-K filed on January 9, 2012, File No. 000-00404)

3.2 By-laws of CL&P, as amended and restated effective September 29, 2014 (Exhibit 3.1, CL&P Current Report on Form 8-K filed October 2, 2014, File No. 000-00404)

(C)    NSTAR Electric Company

3.1 Restated Articles of Organization of NSTAR Electric Company, fka Boston Edison Company (Exhibit 3.1, NSTAR Electric Form 10-Q for the Quarter Ended June 30, 1994 filed August 12, 1994, File No. 001-02301)

3.2 Bylaws of NSTAR Electric Company, as amended and restated effective September 29, 2014 (Exhibit 3.1, NSTAR Electric Current Report on Form 8-K filed October 2, 2014, File No. 000-02301)

(D)    Public Service Company of New Hampshire

3.1 Articles of Incorporation, as amended to May 16, 1991 (Exhibit 3.3.1, 1993 PSNH Form 10-K filed March 25, 1994, File No. 001-06392)

3.2 By-laws of PSNH, as in effect June 27, 2008 (Exhibit 3, PSNH Form 10-Q for the Quarter Ended June 30, 2008 filed August 7, 2008, File No. 001-06392)

4.    Instruments defining the rights of security holders, including indentures

(A)    Eversource Energy

4.1 Indenture between Eversource Energy and The Bank of New York as Trustee dated as of April 1, 2002 (Exhibit A-3, Eversource Energy 35-CERT filed April 16, 2002, File No. 070-09535)

4.1.1 Fifth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of May 1, 2013, relating to $450 million of Senior Notes, Series F, due 2023 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed May 16, 2013, File No. 001-05324)

4.1.2 Sixth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of January 1, 2015, relating to $300 million of Senior Notes, Series H, due 2025 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed January 21, 2015, File No. 001-05324)

4.1.3 Seventh Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of March 7, 2016, relating to $250 million of Senior Notes, Series I, due 2021 and $250 million of Senior Notes, Series J, due 2026 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed March 15, 2016, File No. 001-05324)

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4.1.4 Eighth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of March 10, 2017, relating to $300 million of Senior Notes, Series K, Due 2022 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed March 16, 2017, File No. 001-05324)

4.1.5 Ninth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of October 1, 2017, relating to $450 million of Senior Notes, Series K, due 2022 and $450 million of Senior Notes, Series L, due 2024 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed October 12, 2017, File No. 001-05324)

4.1.6 Tenth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of January 1, 2018, relating to $200 million of Senior Notes, Series I, Due 2021 and $450 million of Senior Notes, Series M, Due 2028 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed January 12, 2018, File No. 001-05324)

4.1.7 Eleventh Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of December 1, 2018, relating to $400 million of Senior Notes, Series N, Due 2023 and $500 million of Senior Notes, Series O, Due 2029 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed December 18, 2018, File No. 001-05324)

4.2 Indenture dated as of January 12, 2000, between Eversource Energy, as successor to NSTAR LLC, as successor to NSTAR, and Bank One Trust Company N.A. (Exhibit 4.1 to NSTAR Registration Statement on Form S-3, filed January 14, 2000, on File No. 333-94735)

4.2.1 Form of 4.50% Debenture Due 2019 (Exhibit 99.2, NSTAR Form 8-K filed November 16, 2009, File No. 001-14768)

*4.3 Eversource Energy Description of Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934

(B)    The Connecticut Light and Power Company

4.1 Indenture of Mortgage and Deed of Trust between CL&P and Bankers Trust Company, Trustee, dated as of May 1, 1921 (Composite including all twenty-four amendments to May 1, 1967) (Exhibit 4.1, 2017 Eversource 10-K filed on February 26, 2018)

4.1.1 Series D Supplemental Indentures to the Composite May 1, 1921 Indenture of Mortgage and Deed of Trust between CL&P and Bankers Trust Company, dated as of October 1, 1994 (Exhibit 4.2.16, 1994 CL&P Form 10-K filed March 27, 1995, File No. 001-11419)

4.1.2 Series B Supplemental Indenture between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of September 1, 2004 (Exhibit 99.5, CL&P Current Report on Form 8-K filed September 22, 2004, File No. 000-00404)

4.2 Composite Indenture of Mortgage and Deed of Trust between CL&P and Deutsche Bank Trust Company Americas f/k/a Bankers Trust Company, dated as of May 1, 1921, as amended and supplemented by seventy-three supplemental mortgages to and including Supplemental Mortgage dated as of April 1, 2005 (Exhibit 99.5, CL&P Current Report on Form 8-K filed April 13, 2005, File No. 000-00404)

4.2.1 Supplemental Indenture (2005 Series B Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of April 1, 2005 (Exhibit 99.2, CL&P Current Report on Form 8-K filed April 13, 2005, File No. 000-00404)

4.2.2 Supplemental Indenture (2006 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of June 1, 2006 (Exhibit 99.2, CL&P Current Report on Form 8-K filed June 7, 2006, File No. 000-00404)

4.2.3 Supplemental Indenture (2007 Series B Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of March 1, 2007 (Exhibit 99.2, CL&P Current Report on Form 8-K filed March 29, 2007, File No. 000-00404)

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4.2.4 Supplemental Indenture (2007 Series D Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of September 1, 2007 (Exhibit 4, CL&P Current Report on Form 8-K filed September 19, 2007, File No. 000-00404)

4.2.5 Supplemental Indenture (2009 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of February 1, 2009 (Exhibit 4, CL&P Current Report on Form 8-K filed February 19, 2009, File No. 000-00404)

4.2.6 Supplemental Indenture (2013 Series A Bond) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of January 1, 2013 (Exhibit 4.1, CL&P Current Report on Form 8-K filed January 22, 2013, File No. 000-00404)

4.2.7 Supplemental Indenture (2014 Series A Bond) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of April 1, 2014 (Exhibit 4.1, CL&P Current Report on Form 8-K filed April 29, 2014, File No. 000-00404)

4.2.8 Supplemental Indenture (2015 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of May 1, 2015 (Exhibit 4.1, CL&P Current Report on Form 8-K filed May 26, 2015, File No. 000-00404)

4.2.9 Supplemental Indenture (2015 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of November 1, 2015 (Exhibit 4.1, CL&P Current Report on Form 8-K filed December 4, 2015, File No. 000-00404)

4.2.10 Supplemental Indenture (2017 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of March 1, 2017 (Exhibit 4.1, CL&P Current Report on Form 8-K filed on March 16, 30017, File No. 000-00404)

4.2.11 Supplemental Indenture (2014 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of August 1, 2017 (Exhibit 4.1, CL&P Current Report on Form 8-K filed August 23, 2017, File No. 000-00404)

4.2.12 Supplemental Indenture (2018 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of March 1, 2018 (Exhibit 4.1, CL&P Current Report on Form 8-K filed April 2, 2018, File No. 000-00404)

4.2.13 Supplemental Indenture (2018 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of March 1, 2019 (Exhibit 4.1, CL&P Current Report on Form 8-K filed on April 4, 2019, File No. 000-00404)

4.2.14 Supplemental Indenture (2017 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of September 1, 2019 (Exhibit 4.1, CL&P Current Report on Form 8-K filed on September 23, 2019, File No. 000-00404)

4.3 Loan Agreement between Connecticut Development Authority and CL&P (Pollution Control Revenue Refunding Bonds - 2011A Series) dated as of October 1, 2011 (Exhibit 1.1, CL&P Current Report on Form 8-K filed October 28, 2011, File No. 000-00404)

*4.4 CL&P Description of Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934

(C) NSTAR Electric Company

4.1 Indenture between Boston Edison Company and the Bank of New York (as successor to Bank of Montreal Trust Company) (Exhibit 4.1, 2017 Eversource Form 10-K filed February 26, 2018)

4.1.1 A Form of 5.75% Debenture Due March 15, 2036 (Exhibit 99.2, Boston Edison Company Current Report on Form 8‑K filed March 17, 2006, File No. 001-02301)

4.1.2 A Form of 5.50% Debenture Due March 15, 2040 (Exhibit 99.2, NSTAR Electric Company Current Report on Form 8‑K filed March 15, 2010, File No. 001-02301)

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4.1.3 A Form of 2.375% Debenture Due 2022 (Exhibit 4, NSTAR Electric Company Current Report on Form 8-K filed October 18, 2012, File No. 001-02301)

4.1.4 A Form of 4.40% Debenture Due 2044 (Exhibit 4, NSTAR Electric Company Current Report on Form 8-K filed March 13, 2014, File No. 001-02301)

4.1.5 A Form of 3.25% Debenture due 2025 (Exhibit 4, NSTAR Electric Company Current Report on Form 8-K filed on November 20, 2015, File No. 001-02301)

4.1.6 A Form of 2.70% Debenture due 2026 (Exhibit 4, NSTAR Electric Company Current Report on Form 8-K filed on May, 31, 2016, File No. 001-02301)

4.1.7 Form of 3.20% Debenture due May 15, 2027 (Exhibit 4, NSTAR Electric Company Current Report on Form 8-K/A filed on October 12, 2017 File No. 001-02301)

4.1.8 Form of 3.25% Debenture due May 15, 2029 (Exhibit 4, NSTAR Electric Company Current Report on Form 8-K filed on May 23, 2019, File No. 001-02301)

4.2 Amended and Restated Credit Agreement, dated December 8, 2017, by and between NSTAR Electric Company and the Banks named therein, pursuant to which Barclays Bank PLC serves as Administrative Agent and Swing Line Lender (Exhibit 4.2, 2017 Eversource Form 10-K filed on February 26, 2018)

4.3 Indenture between NSTAR Electric Company, as successor to Western Massachusetts Electric Company (WMECO), and The Bank of New York, as Trustee, dated as of September 1, 2003 (Exhibit 99.2, WMECO Current Report on Form 8-K filed October 8, 2003, File No. 000-07624)

4.3.1 Second Supplemental Indenture between NSTAR Electric Company, as successor to WMECO, and The Bank of New York, as Trustee dated as of September 1, 2004 (Exhibit 4.1, WMECO Current Report on Form 8-K filed September 27, 2004, File No. 000-07624)

4.3.2 Fourth Supplemental Indenture between NSTAR Electric Company, as successor to WMECO, and The Bank of New York Trust, as Trustee, dated as of August 1, 2007 (Exhibit 4.1, WMECO Current Report on Form 8-K filed August 20, 2007, File No. 000-07624)

4.3.3 Fifth Supplemental Indenture between NSTAR Electric Company, as successor to WMECO, and The Bank of New York Trust Company, N.A., as Trustee, dated as of March 1, 2010 (Exhibit 4.1, Exhibit 4.1, WMECO Current Report on Form 8-K filed March 10, 2010, File No. 000-07624)

4.3.4 Sixth Supplemental Indenture between NSTAR Electric Company, as successor to WMECO, and The Bank of New York Trust Company, N.A., as Trustee, dated as of September 15, 2011 (Exhibit 4.1, WMECO Current Report on Form 8-K filed September 19, 2011, File No. 000-07624)

4.3.5 Seventh Supplemental Indenture between NSTAR Electric Company, as successor to WMECO, and The Bank of New York Trust Company, N.A., as Trustee, dated as of November 1, 2013 (Exhibit 4.1, WMECO Current Report on Form 8-K filed November 21, 2013, File No. 000-07624)

4.3.6 Eighth Supplemental Indenture between NSTAR Electric Company, as successor to WMECO, and The Bank of New York Trust Company, N.A., as Trustee, dated as of June 1, 2016 (Exhibit 4.1, WMECO Current Report on Form 8-K filed June 29, 2016, File No. 000-07624)

*4.4 NSTAR Electric Company Description of Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934

(D)    Public Service Company of New Hampshire

4.1 First Mortgage Indenture between PSNH and First Fidelity Bank, National Association, New Jersey, now First Union National Bank, Trustee, dated as of August 15, 1978 (Composite including all amendments effective June 1, 2011) (included as Exhibit C to the Eighteenth Supplemental Indenture filed as Exhibit 4.1 to PSNH Current Report on Form 8-K filed June 2, 2011, File No. 001-06392)

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4.1.1 Fourteenth Supplemental Indenture between PSNH and Wachovia Bank, National Association successor to First Union National Bank, as successor to First Fidelity Bank, National Association, as Trustee dated as of October 1, 2005 (Exhibit 99.2, PSNH Current Report on Form 8-K filed October 6, 2005, File No. 001-06392)

4.1.2 Seventeenth Supplemental Indenture, between PSNH and U.S. Bank National Association, as Trustee dated as of December 1, 2009 (Exhibit 4.1, PSNH Current Report on Form 8-K filed December 15, 2009 (File No. 001-06392)

4.1.3 Eighteenth Supplemental Indenture, between PSNH and U.S. Bank National Association, as Trustee dated as of May 1, 2011 (Exhibit 4.1, PSNH Current Report on Form 8-K filed June 2, 2011 (File No. 001-06392)

4.1.4 Nineteenth Supplemental Indenture, between PSNH and U.S. Bank National Association, as Trustee dated as of September 1, 2011 (Exhibit 4.1, PSNH Current Report on Form 8-K filed September 16, 2011 (File No. 001-06392)

4.1.5 Twentieth Supplemental Indenture, between PSNH and U.S. Bank National Association, as Trustee dated as of November 1, 2013 (Exhibit 4.1, PSNH Current Report on Form 8-K filed November 20, 2013 (File No. 001-06392)

4.1.6 Twenty-first Supplemental Indenture, between PSNH and U.S. Bank National Association, as Trustee dated as of October 1, 2014 (Exhibit 4.1, PSNH Current Report on Form 8-K filed October 17, 2014 (File No. 001-06392)

4.1.7 Twenty-second Supplemental Indenture, between PSNH and U.S. Bank National Association, as Trustee dated as of June 1, 2019 (Exhibit 4.1, PSNH Current Report on Form 8-K filed on July 3, 2019 (File No. 001-06392)

4.2 Series A Loan and Trust Agreement among Business Finance Authority of the State of New Hampshire and PSNH and State Street Bank and Trust Company, as Trustee (Tax Exempt Pollution Control Bonds) dated as of October 1, 2001 (Exhibit 4.3.4, 2001 Eversource Energy Form 10-K filed March 22, 2002, File No. 001-05324)    

(F) Eversource Energy, The Connecticut Light and Power Company and Public Service Company of New Hampshire

4.1 Amended and Restated Credit Agreement, dated December 8, 2017, by and among Eversource Energy, CL&P, NSTAR Gas, PSNH and Yankee Gas Services Company and the Banks named therein, pursuant to which Bank of America, N.A. serves as Administrative Agent (Exhibit 4.1, 2017 Eversource Form 10-K filed on February 26, 2018)

10.    Material Contracts

(A)    Eversource Energy

10.1 Lease between The Rocky River Realty Company and Eversource Energy Service Company, dated as of July 1, 2008 (Exhibit 10.1, 2017 Eversource Form 10-K filed on February 26, 2018)

*+10.2     Eversource Energy Board of Trustees’ Compensation Arrangement Summary 

+10.3 Amended and Restated Memorandum Agreement between Eversource Energy and Leon J. Olivier effective January 1, 2009 (Exhibit 10.9, 2008 Eversource Energy Form 10-K filed February 27, 2009, File No. 001-05324)

+10.4 Eversource Supplemental Executive Retirement Program effective as of January 1, 2015 (Exhibit 10.5, 2015 Eversource Energy Form 10-K filed February 26, 2016, File No. 001-05324)

+10.5 Composite Transmission Service Agreement, by and between Northern Pass Transmission LLC, as Owner and H.Q. Hydro Renewable Energy, Inc., as Purchaser dated October 4, 2010 and effective February 14, 2014 (Exhibit 10.5, 2013 Eversource Energy Form 10-K filed on February 25, 2014, File No. 001-05324)

10.6 Eversource Energy Deferred Compensation Plan for Executives effective as of January 1, 2014 (Exhibit 10.6, 2015 Eversource Energy Form 10-K filed February 26, 2016, File No. 001-05324)

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*+10.6.1    Amendment No 1 to the Eversource Deferred Compensation Plan effective February 7, 2018

+10.7 NSTAR Excess Benefit Plan, effective August 25, 1999 (Exhibit 10.1 1999 NSTAR Form 10-K/A filed September 29, 2000, File No. 001-14768)

+10.7.1 NSTAR Excess Benefit Plan, incorporating the NSTAR 409A Excess Benefit Plan, as amended and restated effective January 1, 2008, dated December 24, 2008 (Exhibit 10.1.1 2008 NSTAR Form 10-K filed February 9, 2009, File No. 001-14768)

+10.8 Amended and Restated Change in Control Agreement by and between James J. Judge and NSTAR, dated November 15, 2007 (Exhibit 10.9, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.9 Amended and Restated Change in Control Agreement by and between Joseph R. Nolan, Jr. and NSTAR, dated November 15, 2007 (Exhibit 10.13, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.10 Amended and Restated Change in Control Agreement by and between Werner J. Schweiger and NSTAR, dated November 15, 2007 (Exhibit 10.14, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.11 Amended and Restated Change in Control Agreement by and between Senior Vice President and NSTAR, dated November 15, 2007 (Exhibit 10.15, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.12 Master Trust Agreement between NSTAR and State Street Bank and Trust Company (Rabbi Trust), effective August 25, 1999 (Exhibit 10.5, NSTAR Form 10-Q for the Quarter Ended September 30, 2000 filed November 14, 2000, File No. 001-14768)

+10.13 Currently effective Change in Control Agreement between NSTAR’s Vice Presidents and NSTAR (in form) (Exhibit 10.17, 2009 NSTAR Form 10-K filed February 25, 2010, File No. 001-14768)

10.14 Forward Sale Agreement between Eversource Energy and Goldman Sachs & Co. LLC, dated as of May 30, 2019 (Exhibit 10.1, Eversource Energy Current Report on Form 8-K filed on July 3, 2019 (File No. 001-06392)

(B) Eversource Energy, The Connecticut Light and Power Company, NSTAR Electric Company and Public Service Company of New Hampshire

10.1 Amended and Restated Form of Service Contract between each of Eversource Energy, CL&P, NSTAR Electric Company and Eversource Energy Service Company dated as of January 1, 2014. (Exhibit 10.1, Eversource Energy Form 10-K filed on February 25, 2014, File No. 001-05324)

10.2 Transmission Operating Agreement between the Initial Participating Transmission Owners, Additional Participating Transmission Owners and ISO New England, Inc. dated as of February 1, 2005 (Exhibit 10.29, 2004 Eversource Energy Form 10-K filed March 17, 2005, File No. 001-05324)

10.2.1 Rate Design and Funds Disbursement Agreement among the Initial Participating Transmission Owners, Additional Participating Transmission Owners and ISO New England, Inc., effective June 30, 2006 (Exhibit 10.22.1, 2006 Eversource Energy Form 10-K filed March 1, 2007, File No. 001-05324)

10.3 Eversource Energy's Third Amended and Restated Tax Allocation Agreement dated as of April 10, 2012, (Exhibit 10.1 Eversource Energy Form 10-Q for Quarter Ended June 30, 2012 filed August 7, 2012, File No. 001-05324)

+10.4 Amended and Restated Incentive Plan Effective January 1, 2009 (Exhibit 10.3, Eversource Energy Form 10-Q for the Quarter Ended September 30, 2008 filed November 10, 2008, File No. 001-05324)

+10.5 2018 Eversource Energy Incentive Plan (Exhibit 99.2, Eversource Energy Current Report on Form 8-K dated May 3, 2018)

+10.6 Trust under Supplemental Executive Retirement Plan dated May 2, 1994 (Exhibit 10.33, 2002 Eversource Energy Form 10-K filed March 21, 2003, File No. 001-05324)

+10.6.1 First Amendment to Trust Under Supplemental Executive Retirement Plan, effective as of December 10, 2002 (Exhibit 10 (B) 10.19.1, 2003 Eversource Energy Form 10-K filed March 12, 2004, File No. 001-05324)

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+10.6.2 Second Amendment to Trust Under Supplemental Executive Retirement Plan, effective as of November 12, 2008 (Exhibit 10.12.2, 2008 Eversource Energy Form 10-K filed February 27, 2009, File No. 001-05324)

+10.7 Special Severance Program for Officers of Eversource Energy Companies as of January 1, 2009 (Exhibit 10.2 Eversource Energy Form 10-Q for Quarter Ended September 30, 2008 filed November 10, 2008, File No. 001-05324)

+10.8 Amended and Restated Employment Agreement with Gregory B. Butler, effective January 1, 2009 (Exhibit 10.7, 2008 Eversource Energy 2010 Form 10-K filed February 27, 2009, File No. 001-05324)

(C) Eversource Energy, The Connecticut Light and Power Company, Public Service Company of New Hampshire and NSTAR Electric Company

10.1    Agreements among New England Utilities with respect to the Hydro-Quebec interconnection projects

10.1.1 Composite conformed copy of Equity Funding Agreement for New England Hydro-Transmission Electric Company., dated as of June 1, 1985 (Massachusetts) (Exhibit 10.1.1, 2017 Eversource Form 10-K filed February 26, 2018)

10.1.2 Composite conformed copy of Equity Funding Agreement of Equity Funding Agreement for New England Hydro-Transmission Electric Company, Inc., dated as of June 1, 1985 (New Hampshire) (Exhibit 10.1.2, 2017 Eversource Form 10-K filed February 26, 2018)

10.1.3 Composite conformed copy of Phase II Massachusetts Transmission Facilities Support Agreement, dated as of June 1, 1985 (Exhibit 10.1.3, 2017 Eversource Form 10-K filed February 26, 2018)

10.1.4 Composite conformed copy of Phase II New England Power AC Facilities Support Agreement dated June 1, 1985 (Exhibit 10.1.4, 2017 Eversource Form 10-K filed on February 26, 2018)

10.1.5 Composite conformed copy of Phase II New Hampshire Transmission Facilities Support Agreement dated as of June 1, 1985 (Exhibit 10.1.5, Eversource 10-K filed on February 26, 2018)

10.2 Eversource Energy Service Company Transmission and Ancillary Service Wholesale Revenue Allocation Methodology among The Connecticut Light and Power Company, NSTAR Electric Company, Public Service Company of New Hampshire, Holyoke Water Power Company and Holyoke Power and Electric Company Trustee dated as of January 1, 2008 (Exhibit 10.1, Eversource Energy Form 10-Q for the Quarter Ended March 31, 2008 filed May 9, 2008, File No. 001-05324)

(D)    Eversource Energy and The Connecticut Light and Power Company

10.1 CL&P Agreement Re: Connecticut NEEWS Projects by and between CL&P and The United Illuminating Company dated July 14, 2010 (Exhibit 10, CL&P Form 10-Q for the Quarter Ended June 30, 2010 filed August 6, 2010, File No. 000-00404)

*21.    Subsidiaries of the Registrant

*23.    Consents of Independent Registered Public Accounting Firm

*31.    Rule 13a - 14(a)/15 d - 14(a) Certifications

(A) Eversource Energy

31 Certification by the Chief Executive Officer of Eversource Energy pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.1 Certification by the Chief Financial Officer of Eversource Energy pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

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(B) The Connecticut Light and Power Company

31 Certification by the Chairman of CL&P pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.1 Certification by the Chief Financial Officer of CL&P pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

(C) NSTAR Electric Company

31 Certification by the Chairman of NSTAR Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.1 Certification by the Chief Financial Officer of NSTAR Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

(D) Public Service Company of New Hampshire

31 Certification by the Chairman of PSNH pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

31.1 Certification by the Chief Financial Officer of PSNH pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

*32    18 U.S.C. Section 1350 Certifications

(A) Eversource Energy

32 Certification by the Chief Executive Officer and Chief Financial Officer of Eversource Energy pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

(B) The Connecticut Light and Power Company

32 Certification by the Chairman and the Chief Financial Officer of CL&P pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

(C) NSTAR Electric Company

32 Certification by the Chairman and the Chief Financial Officer of NSTAR Electric Company pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

(D) Public Service Company of New Hampshire

32 Certification by the Chairman and the Chief Financial Officer of PSNH pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

*101.INS Inline XBRL Instance Document - the instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document

*101.SCH    Inline XBRL Taxonomy Extension Schema

*101.CAL    Inline XBRL Taxonomy Extension Calculation

*101.DEF    Inline XBRL Taxonomy Extension Definition

*101.LAB    Inline XBRL Taxonomy Extension Labels

*101.PRE    Inline XBRL Taxonomy Extension Presentation

*104 The cover page from the Annual Report on Form 10-K for the year ended December 31, 2019, formatted in Inline XBRL

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EVERSOURCE ENERGY

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		EVERSOURCE ENERGY
February 26, 2020	By:	/s/	Jay S. Buth
			Jay S. Buth
			Vice President, Controller and Chief Accounting 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 and on the dates indicated.

POWER OF ATTORNEY

Each person whose signature appears below constitutes and appoints Gregory B. Butler, Philip J. Lembo and Jay S. Buth and each of them, his or her true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him or her and in his or her name, place and stead, in any and all capacities, to sign any and all amendments to this Annual Report on Form 10-K, and to file the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done, as fully to all intents and purposes as he or she might or could do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them, or their or his or her substitute or substitutes, may lawfully do or cause to be done by virtue hereof.

	Signature	Title	Date
/s/	James J. Judge	Chairman of the Board, President and	February 26, 2020
	James J. Judge	Chief Executive Officer and a Trustee
		(Principal Executive Officer)
/s/	Philip J. Lembo	Executive Vice President	February 26, 2020
	Philip J. Lembo	and Chief Financial Officer
		(Principal Financial Officer)
/s/	Jay S. Buth	Vice President, Controller	February 26, 2020
	Jay S. Buth	and Chief Accounting Officer
/s/	Cotton M. Cleveland	Trustee	February 26, 2020
	Cotton M. Cleveland
/s/	Sanford Cloud, Jr.	Trustee	February 26, 2020
	Sanford Cloud, Jr.

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	Signature	Title	Date
/s/	James S. DiStasio	Trustee	February 26, 2020
	James S. DiStasio
/s/	Francis A. Doyle	Trustee	February 26, 2020
	Francis A. Doyle
/s/	Linda Dorcena Forry	Trustee	February 26, 2020
	Linda Dorcena Forry
/s/	John Y. Kim	Trustee	February 26, 2020
	John Y. Kim
/s/	Kenneth R. Leibler	Trustee	February 26, 2020
	Kenneth R. Leibler
/s/	David H. Long	Trustee	February 26, 2020
	David H. Long
/s/	William C. Van Faasen	Trustee	February 26, 2020
	William C. Van Faasen
/s/	Frederica M. Williams	Trustee	February 26, 2020
	Frederica M. Williams

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THE CONNECTICUT LIGHT AND POWER COMPANY

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	THE CONNECTICUT LIGHT AND POWER COMPANY
February 26, 2020	By:	/s/	Jay S. Buth
			Jay S. Buth
			Vice President, Controller and Chief Accounting 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 and on the dates indicated.

POWER OF ATTORNEY

Each person whose signature appears below constitutes and appoints Gregory B. Butler, Philip J. Lembo and Jay S. Buth and each of them, his true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him and in his name, place and stead, in any and all capacities, to sign any and all amendments to this Annual Report on Form 10-K, and to file the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done, as fully to all intents and purposes as he might or could do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them, or their or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.

	Signature	Title	Date
/s/	James J. Judge	Chairman and a Director	February 26, 2020
	James J. Judge	(Principal Executive Officer)
/s/	Werner J. Schweiger	Chief Executive Officer and a Director	February 26, 2020
	Werner J. Schweiger
/s/	Philip J. Lembo	Executive Vice President and	February 26, 2020
	Philip J. Lembo	Chief Financial Officer and a Director
		(Principal Financial Officer)
/s/	Gregory B. Butler	Executive Vice President and General Counsel	February 26, 2020
	Gregory B. Butler	and a Director
/s/	Jay S. Buth	Vice President, Controller	February 26, 2020
	Jay S. Buth	and Chief Accounting Officer

E-11

NSTAR ELECTRIC COMPANY

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	NSTAR ELECTRIC COMPANY
February 26, 2020	By:	/s/	Jay S. Buth
			Jay S. Buth
			Vice President, Controller and Chief Accounting 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 and on the dates indicated.

POWER OF ATTORNEY

Each person whose signature appears below constitutes and appoints Gregory B. Butler, Philip J. Lembo and Jay S. Buth and each of them, his true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him and in his name, place and stead, in any and all capacities, to sign any and all amendments to this Annual Report on Form 10-K, and to file the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done, as fully to all intents and purposes as he might or could do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them, or their or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.

	Signature	Title	Date
/s/	James J. Judge	Chairman and a Director	February 26, 2020
	James J. Judge	(Principal Executive Officer)
/s/	Werner J. Schweiger	Chief Executive Officer and a Director	February 26, 2020
	Werner J. Schweiger
/s/	Philip J. Lembo	Executive Vice President and	February 26, 2020
	Philip J. Lembo	Chief Financial Officer and a Director
		(Principal Financial Officer)
/s/	Gregory B. Butler	Executive Vice President and General Counsel	February 26, 2020
	Gregory B. Butler	and a Director
/s/	Jay S. Buth	Vice President, Controller	February 26, 2020
	Jay S. Buth	and Chief Accounting Officer

E-12

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
February 26, 2020	By:	/s/	Jay S. Buth
			Jay S. Buth
			Vice President, Controller and Chief Accounting 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 and on the dates indicated.

POWER OF ATTORNEY

Each person whose signature appears below constitutes and appoints Gregory B. Butler, Philip J. Lembo and Jay S. Buth and each of them, his true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him and in his name, place and stead, in any and all capacities, to sign any and all amendments to this Annual Report on Form 10-K, and to file the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done, as fully to all intents and purposes as he might or could do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents or any of them, or their or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.

	Signature	Title	Date
/s/	James J. Judge	Chairman and a Director	February 26, 2020
	James J. Judge	(Principal Executive Officer)
/s/	Werner J. Schweiger	Chief Executive Officer and a Director	February 26, 2020
	Werner J. Schweiger
/s/	Philip J. Lembo	Executive Vice President and	February 26, 2020
	Philip J. Lembo	Chief Financial Officer and a Director
		(Principal Financial Officer)
/s/	Gregory B. Butler	Executive Vice President and General Counsel	February 26, 2020
	Gregory B. Butler	and a Director
/s/	Jay S. Buth	Vice President, Controller	February 26, 2020
	Jay S. Buth	and Chief Accounting Officer

E-13

EX-4.3

Exhibit 4.3

DESCRIPTION OF THE REGISTRANT’S SECURITIES

REGISTERED PURSUANT TO SECTION 12 OF THE SECURITIES

EXCHANGE ACT OF 1934

Eversource Energy

Description of Common Shares and Preferred Shares

The following summary of the terms of our Common Shares and Preferred Shares is based upon Eversource Energy’s Declaration of Trust (the “Declaration of Trust”). The summary is not complete, and is qualified by reference to our Declaration of Trust filed as an exhibit to the Annual Report on Form 10-K of which the exhibit is a part. We encourage you to read the applicable provisions of our Declaration of Trust for additional information.

Common Shares and Preferred Shares

Common Shares. Our outstanding common shares are listed on the New York Stock Exchange (NYSE) and trade under the symbol “ES.” Any additional common shares we issue will also be listed on the NYSE. Common shareholders may receive dividends if and when declared by our Board of Trustees. Dividends may be paid in cash, shares or other form. All outstanding common shares are fully paid and non-assessable. Any additional common shares we issue will also be fully paid and non-assessable.

Each common share is entitled to one vote in the election of Trustees and other matters. Common shareholders are not entitled to cumulative voting rights. Eversource Energy will notify common shareholders of any shareholders’ meetings according to applicable law. If we liquidate, dissolve or wind up our business, either voluntarily or not, common shareholders will share equally in the assets remaining after we pay our creditors and preferred shareholders, if any.

Preferred Shares. Eversource Energy does not currently have preferred shares authorized, although the Declaration of Trust permits the issuance of preferred shares subject to common shareholder approval. Before Eversource Energy can issue preferred shares, the company will need to obtain authorization from the Board of Trustees and common shareholders. If Eversource Energy issues preferred shares, the specific designations and rights will be described in a prospectus supplement and a description will be filed with the Commission.

Preferred shares will have such par value, if any, such priority in liquidation, such voting rights and such other rights, privileges, preferences, restrictions and limitations as may be established by our Board of Trustees and approved by our common shareholders. In some cases, the issuance of preferred shares could delay a change in control of the Company and make it harder to remove present management. Under certain circumstances, Preferred Shares could also restrict dividend payments to holders of common shares.

The preferred shares will, when authorized and issued, be fully paid and non-assessable. Unless otherwise specified in the applicable prospectus supplement, the preferred shares will rank on parity in all respects with any outstanding preferred shares we may have at that time and will have priority over our common shares as to dividends and distributions of assets. Therefore, the rights of any preferred shares may limit the rights of the holders of our common shares.

EX-4.4

Exhibit 4.4

DESCRIPTION OF THE REGISTRANT’S SECURITIES

REGISTERED PURSUANT TO SECTION 12 OF THE SECURITIES

EXCHANGE ACT OF 1934

The Connecticut Light and Power Company

Description of Capital Stock

The following summary of the terms of our Capital Stock is based upon CL&P’s Amended and Restated Certificate of Incorporation (the “Certificate of Incorporation”) and CL&P’s Amended and Restated Bylaws (the “Bylaws”). The summary is not complete, and is qualified by reference to our Certificate of Incorporation and Bylaws, which are filed as exhibits to the Annual Report on Form 10-K of which this exhibit is a part. We encourage you to read the applicable provisions of the CL&P Certificate of Incorporation and Bylaws for additional information.

Capital Stock

The capital stock of CL&P consists of two classes designated, respectively, “Preferred Stock” and “Common Stock.” The authorized number of shares of Preferred Stock with par value $50 per share is 9,000,000 shares. The authorized number of shares of Common Stock with par value of $10 per share is 24,500,000 shares.

Preferred Stock. The holders of any series of the Preferred Stock shall receive, when declared by the Board of Directors, preferential dividends at such rate and payable on such dividend payment dates in each year as the Board may determine for any series. The Common Stock and any other stock of the Company is subordinate to the Preferred Stock in respect of dividends or payment in case of liquidation.

The holders of any series of the Preferred Stock at any time outstanding may be called by vote of the Board of Directors for redemption at any time. Except as provided in the Certificate of Incorporation, and as provided by law, the holders of the Preferred Stock shall have no voting power, except if dividends are in arrears or CL&P shall have been declared bankrupt. Whenever holders of Preferred Stock have the right to vote, each holder of Preferred Stock is entitled to one vote on matters submitted to a vote of stockholders including, if applicable, the election of directors. Holders of Preferred Stock are not entitled to preemptive or conversion rights.

Common Stock. Subject to the rights of holders of Preferred Stock, the holders of Common Stock shall have the dividend, voting, liquidation, preemptive and other rights to which they are entitled under the general corporation law of the State of Connecticut. The holders of the Common Stock shall have no preemptive right to subscribe to any future issues of Preferred Stock (other than Preferred Stock convertible into Common Stock). The Board of Directors has the power to issue and dispose of, from time to time, shares of the authorized and unissued Common Stock at such times, and in such amounts, upon such terms, and in such manner as it may determine, either for cash or property, or for securities convertible into Common Stock, and to fix the amount of money or the actual value of the consideration for which such authorized and unissued Common Stock shall be issued.

EX-4.4

Exhibit 4.4

DESCRIPTION OF THE REGISTRANT’S SECURITIES

REGISTERED PURSUANT TO SECTION 12 OF THE SECURITIES

EXCHANGE ACT OF 1934

NSTAR Electric Company

Description of Capital Stock

The following summary of the terms of our Capital Stock is based upon NSTAR Electric’s Amended and Restated Articles of Organization (the “Articles of Organization”) and Amended and Restated Bylaws (the “Bylaws”). The summary is not complete, and is qualified by reference to our Articles of Organization and Bylaws, which are filed as exhibits to the Annual Report on Form 10-K of which this exhibit is a part. We encourage you to read the applicable provisions of the NSTAR Electric Articles of Organization and Bylaws for additional information.

Capital Stock

The Capital Stock of NSTAR Electric consists of Cumulative Preferred Stock have a par value of $100 per share, Preference Stock having a par value of $1 per share and Common Stock having a par value of $1 per share.

Cumulative Preferred Stock. Except as provided in the Articles of Organization, and as provided by law, the holders of the Cumulative Preferred Stock shall have no rights to vote, except if dividends are in arrears, if changes to the provisions of the Cumulative Preferred Stock are proposed, if a class ranking prior to or on a parity with the Cumulative Preferred Stock is proposed to be issued, or if a merger is contemplated where NSTAR Electric will not be the surviving corporation. Whenever holders of Cumulative Preferred Stock have the right to vote, each holder of Cumulative Preferred Stock is entitled to one vote on matters submitted to a vote of stockholders, including, if applicable, the election of directors. Whenever a vote of the Cumulative Preferred Stock may be required for any purpose, the shares voting, if of different series, shall be counted irrespective of series and not by different series, except as otherwise provided by law or by the Articles of Organization. Holders of Cumulative Preferred Stock are entitled to receive cumulative dividends when and as declared by the board of directors out of funds legally available for the declaration of dividends. NSTAR Electric shall have the right, at its option and by resolution of the board of directors, to redeem the Cumulative Preferred Stock or any series thereof, as a whole at any time, or in part from time to time, upon payment in cash of the redemption price fixed for the shares of a particular series, together with dividends accrued thereon to the redemption date. In the event of NSTAR Electric’s voluntary or involuntary liquidation, dissolution or winding up, holders of Cumulative Preferred Stock shall be entitled to be paid in cash the distributive amount fixed for the particular series, together in each case with dividends accrued thereon to the date fixed for payment of such distributive amounts before distributions are made to holders of Common Stock or any other stock ranking junior to the Cumulative Preferred Stock.

Preference Stock. All shares of Preference Stock shall be identical except as to the designation thereof and except that there may be variations fixed and determined by the board of directors, to the extent to inconsistent with the provisions of the Articles of Organization relating to the Preference Stock, between different series as to the right of redemption and the price, terms and manner of redemption, special and relative rights as to dividends and liquidation, sinking or purchase fund provisions and conversion rights. Subject to the prior preferential rights of the Cumulative Preferred Stock and any other class of stock ranking prior to the Preference Stock with respect to the payment of dividends, the holders of shares of each series of Preference Stock shall be entitled to receive, when, as and if declared by the board of directors, out of funds legally available for the purpose, cash dividends determined in the manner fixed by the board of directors for such series. In the event of NSTAR Electric’s voluntary or involuntary liquidation, dissolution or winding up of the corporation, the holders of shares of each series of Preference Stock shall be entitled, before any distribution or payment is made upon any shares of Common Stock or another other stock ranking junior to the Preference Stock, but subject to the prior preferential rights of the Cumulative Preferred Stock and any other stock ranking prior to the Preference Stock, to be paid the amount fixed

and determined by the board of directors for such series plus an amount equal to the dividends accrued to the date of payment. Except as provided in the Articles of Organization, and as provided by law, the holders of the Preference Stock shall have no voting power, except if dividends are in arrears. Whenever holders of Preference Stock have the right to vote, each holder of Preference Stock is entitled to one vote on matters submitted to a vote of stockholders including, if applicable, the election of directors. No shares of Preference Stock are currently outstanding.

Common Stock. Each share of the Common Stock shall be equal to every other share thereof in all respects. Except as by law or in the Articles of Organization, holders of the Common Stock shall have the exclusive right to vote for the election of directors and for any other purpose or on any other subject and to be represented at and to receive notice of any meeting of stockholders.

EX-10.2

Exhibit 10.2

SUMMARY OF TRUSTEE COMPENSATION ARRANGEMENTS

The Compensation Committee periodically reviews the compensation of our non-employee Trustees and, when it deems appropriate and upon consultation with the Committee’s independent compensation consultant, recommends adjustments to be approved by the Board of Trustees. The Compensation Committee recommends to the Board compensation for the Trustees based on competitive market practices for both the total value of compensation and the allocation of cash and equity. The Committee uses data obtained from similarly sized utility and general industry companies as guidelines for setting Trustee compensation. The level of Trustee compensation recommended by the Committee and approved by the Board enables us to attract Trustees who have a broad range of backgrounds and experiences.

Each non-employee Trustee serving on January 1 receives a grant under the Company’s Incentive Plan, generally effective on the tenth business day of each such year, consisting of the number of restricted stock units (RSUs) resulting from dividing $135,000 by the average closing price of our common shares as reported on the NYSE for the 10 trading days immediately preceding such date and rounding the resulting amount to the nearest whole RSU. RSUs generally vest on the next business day following the grant. Beginning with grants made in 2020, each non-employee Trustee was entitled to elect distribution of up to 100 percent of the common shares issuable in respect of such RSUs immediately upon vesting of their RSU grant, subject to satisfaction of the Trustee share ownership guidelines. The distribution of all common shares entitled to be received upon vesting, but not distributed immediately, are deferred until the tenth business day of January of the year following retirement from Board service. Any individual who is elected to serve as a Trustee after January 1 of any calendar year receives an RSU grant prorated from the date of such election and granted on the first business day of the month following such election.

2019 Trustee Compensation

Compensation Element	Amount
Annual Cash Retainer	$115,000
Annual Stock Retainer	$135,000
Board and Committee Attendance Fees	None
Annual Lead Trustee Retainer	$30,000
Annual Committee Chair Retainer	$20,000 Audit Committee $15,000 Compensation Committee $15,000 Corporate Governance Committee $15,000 Finance Committee

Annual cash retainers of $115,000 per Trustee, additional Committee Chair and Lead Trustee cash retainers and annual RSU grants for service on the Board for 2019 based on the amounts above were paid as described in this section. Pay Governance LLC provided the Compensation Committee with a review of competitive market practices and compensation in 2019. As a result, the annual cash retainer for the Chair of the Audit Committee was increased by $5,000 and the annual RSU grants were increased by $25,000, effective January 1, 2020.

The share ownership guidelines set forth in the Company’s Corporate Governance Guidelines require each Trustee to attain ownership of a number of common shares equal to a market value of at least five-times the then current annual cash compensation retainer for service on the Board. Trustees shall be required to hold all shares awarded as annual stock compensation retainers until the guidelines have been met. All of the current Trustees exceed the required share ownership threshold except for Mr. Kim and Ms. Forry, each of whom was elected as a Trustee in 2018, and Mr. Long, who was elected as a Trustee in 2019.

Pursuant to the Company’s Deferred Compensation Plan, prior to the year earned, each Trustee may irrevocably elect to defer receipt of all or a portion of their cash compensation. Deferred funds are credited with deemed earnings on various deemed investments as permitted by the Deferred Compensation Plan. Deferred cash compensation is payable either in a lump sum or in installments in accordance with the Trustee’s prior election. There were no above-market earnings in deferred compensation value during 2019, as the terms of the Deferred Compensation Plan provide for market-based investments, including Company common shares.

Our 2018 Incentive Plan places a limit on the amount of total annual compensation that can be paid to any Trustee. When applicable, we pay travel-related expenses for spouses of Trustees who attend Board functions, but we do not pay tax gross-up payments in connection with such expenses, nor do we pay pension benefits to our non-employee Trustees.

EX-10.6.1

Exhibit 10.6.1

Amendment Number 1 to the

Eversource Deferred Compensation Plan

Effective February 7, 2018, the Eversource Deferred Compensation Plan is amended as follows:

1. The definition of “Eligible Trustee” in Article 2 is hereby amended to remove “an” and add “a non-Employee” and shall read as follows:

““Eligible Trustee” means any person serving as a non-employee Eversource Energy Trustee for a particular Plan Year.”

2. Article 4.5 (A) is hereby amended to add the percentage amount of any annual Equity Award granted to be automatically deferred and shall read as follows:

“(A) Trustee Equity Award. An Eligible Trustee automatically shall be deemed to elect deferral of fifty percent of any annual Equity Award granted as part of the retainer for Board service for any Plan Year, and may, subject to such rules as the Trustees may adopt from time to time, elect to defer or not defer part or all of the remaining fifty percent of such annual Equity Award.”

3. Article 4.6 (B) is hereby amended to add reference to Equity with respect to deferral elections and shall read as follows:

“(B) Trustee Participants. A Trustee Participant’s Cash and Equity Award Deferral elections for a Particular Year shall terminate as to further deferrals for such Plan Year if such Participant (i) becomes Disabled during such Plan Year, or (ii) receives an Emergency Benefit under the Plan during such Plan Year.”

4. Article 6.2 (A) is hereby amended to clarify the distribution time of a properly deferred Trustee Participant Equity Award and shall read as follows:

“(A) Affirmative Elections by Participants. All distributions from all Employee Participant Accounts and Trustee Participant Cash Retainer Deferral Accounts hereunder shall be made within 60 days of the Participant’s End Termination Date unless other permitted by the Plan Administrator and properly elected in the Participant’s Enrollment Agreement. Distributions from Trustee Participant Equity Deferral Accounts shall be made on the tenth day of January in the year following the Trustee’s Termination Date unless otherwise permitted by the Plan Administrator and properly elected in the Trustee Participant’s Enrollment Agreement. No Enrollment Agreement shall elect a distribution date sooner than 3 years after the Plan Year for which the deferral is to occur (or earlier termination of Service).”

5. Article 6.2 (B) is hereby deleted in its entirety and Article 6.2 (C) is renamed Article 6.2 (B).

6.Article 7.2 is hereby amended by deleting the words “within 90 days” and substituting therein “at the election of the Participant’s beneficiary, but in no event later than December 31 of the year following the Participant’s death”.

EVERSOURCE ENERGY SERVICE COMPANY

_________________________________________

Christine M. Carmody

Executive Vice President - Human Resources and

Information Technology

EX-21

Exhibit 21

Subsidiaries of the Registrants as of February 26, 2020⁽¹⁾ 

	State of Incorporation
Eversource Energy (a Massachusetts business trust) (2)	MA
The Connecticut Light and Power Company (2) (3)	CT
Connecticut Yankee Atomic Power Company (4)	CT
Eversource Energy Service Company	CT
Eversource Energy Transmission Ventures, Inc.	CT
Eversource Gas Transmission LLC	MA
Eversource Gas Transmission II LLC	MA
Eversource LNG Service Company LLC	MA
Northern Pass Transmission LLC	NH
Renewable Properties, Inc.	NH
Eversource Holdco Corporation	MA
Eversource Investment LLC	MA
Eversource Investment Service Company LLC	MA
Eversource Water Ventures, Inc.	CT
Eversource Aquarion Holdings, Inc.	DE
Aquarion Company	DE
Aquarion Water Company	CT
Aquarion Water Company of Connecticut	CT
Aquarion Water Company of Massachusetts, Inc.	MA
Aquarion Water Capital of Massachusetts, Inc.	DE
Aquarion Water Company of New Hampshire, Inc.	NH
Homeowner Safety Valve Company	DE
HWP Company	MA
North Atlantic Energy Corporation	NH
North Atlantic Energy Service Corporation	NH
Northeast Nuclear Energy Company	CT
NSTAR Electric Company (2) (3)	MA
Harbor Electric Energy Company	MA
Public Service Company of New Hampshire (2) (3)	NH
Properties, Inc.	NH
PSNH Funding LLC 3	DE
The Rocky River Realty Company	CT
Yankee Atomic Electric Company (4)	MA
Yankee Energy System, Inc.	CT
Hopkinton LNG Corp.	MA
NSTAR Gas Company (3)	MA
Yankee Gas Services Company (3)	CT

(1) The names of some of our subsidiaries which, if considered in the aggregate as a single subsidiary, would not constitute a “significant subsidiary,” have been omitted in accordance with Item 601(b)(21)(ii) of Regulation S-K.

(2) SEC Registrant.

(3) Each of these entities is doing business as Eversource Energy.

(4) For The Connecticut Light and Power Company, NSTAR Electric Company and Public Service Company of New Hampshire, investments in Connecticut Yankee Atomic Power Company and Yankee Atomic Electric Company are accounted for under the equity method.

EX-23

Exhibit 23

CONSENTS OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We consent to the incorporation by reference in Registration Statement Nos. 333-231118 and 333-224122 on Form S-3 and Registration Statement Nos. 333-121364, 333-142724, 333-181258, 333-224605, and 333-231116 on Form S-8 of our reports dated February 26, 2020, relating to the consolidated financial statements and the financial statement schedules of Eversource Energy and subsidiaries, and the effectiveness of Eversource Energy and subsidiaries' internal control over financial reporting, appearing in this Annual Report on Form 10-K of Eversource Energy for the year ended December 31, 2019.

We also consent to the incorporation by reference in Registration Statement No. 333-231118-01 on Form S-3 of our report dated February 26, 2020, relating to the financial statements and the financial statement schedule of The Connecticut Light and Power Company appearing in this Annual Report on Form 10-K of The Connecticut Light and Power Company for the year ended December 31, 2019.

We also consent to the incorporation by reference in Registration Statement No. 333-231118-02 on Form S-3 of our report dated February 26, 2020, relating to the consolidated financial statements and the financial statement schedule of NSTAR Electric Company and subsidiary appearing in this Annual Report on Form 10-K of NSTAR Electric Company for the year ended December 31, 2019.

We also consent to the incorporation by reference in Registration Statement No. 333-231118-03 on Form S-3 of our report dated February 26, 2020, relating to the consolidated financial statements and the financial statement schedule of Public Service Company of New Hampshire and subsidiary appearing in this Annual Report on Form 10-K of Public Service Company of New Hampshire for the year ended December 31, 2019.

/s/ Deloitte & Touche LLP

Hartford, Connecticut

February 26, 2020

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.I have reviewed this Annual Report on Form 10-K of Eversource Energy (the registrant);

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

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

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

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

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

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

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

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

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

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

Date:  February 26, 2020

/s/	James J. Judge
	James J. Judge
	Chairman of the Board, President and Chief Executive Officer
	(Principal Executive Officer)

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.I have reviewed this Annual Report on Form 10-K of The Connecticut Light and Power Company (the registrant);

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

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

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

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

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

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

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

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

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

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

Date:  February 26, 2020

/s/	James J. Judge
	James J. Judge
	Chairman
	(Principal Executive Officer)

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.I have reviewed this Annual Report on Form 10-K of NSTAR Electric Company (the registrant);

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

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

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

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

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

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

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

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

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

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

Date:  February 26, 2020

/s/	James J. Judge
	James J. Judge
	Chairman
	(Principal Executive Officer)

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.I have reviewed this Annual Report on Form 10-K of Public Service Company of New Hampshire (the registrant);

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

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

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

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

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

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

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

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

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

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

Date:  February 26, 2020

/s/	James J. Judge
	James J. Judge
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.I have reviewed this Annual Report on Form 10-K of Eversource Energy (the registrant);

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

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

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

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

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

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

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

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

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

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

Date:  February 26, 2020

/s/	Philip J. Lembo
	Philip J. Lembo
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.I have reviewed this Annual Report on Form 10-K of The Connecticut Light and Power Company (the registrant);

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

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

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

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

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

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

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

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

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

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

Date:  February 26, 2020

/s/	Philip J. Lembo
	Philip J. Lembo
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.I have reviewed this Annual Report on Form 10-K of NSTAR Electric Company (the registrant);

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

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

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

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

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

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

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

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

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

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

Date:  February 26, 2020

/s/	Philip J. Lembo
	Philip J. Lembo
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.I have reviewed this Annual Report on Form 10-K of Public Service Company of New Hampshire (the registrant);

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

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

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

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

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

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

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

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

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

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

Date:  February 26, 2020

/s/	Philip J. Lembo
	Philip J. Lembo
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Annual Report on Form 10-K of Eversource Energy (the registrant) for the period ending December 31, 2019 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, Chairman of the Board, President and Chief Executive Officer of the registrant, and Philip J. Lembo, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	Chairman of the Board, President and Chief Executive Officer

/s/	Philip J. Lembo
	Philip J. Lembo
	Executive Vice President and Chief Financial Officer

Date:  February 26, 2020

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Annual Report on Form 10-K of The Connecticut Light and Power Company (the registrant) for the period ending December 31, 2019 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, Chairman of the registrant, and Philip J. Lembo, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	Chairman

/s/	Philip J. Lembo
	Philip J. Lembo
	Executive Vice President and Chief Financial Officer

Date:  February 26, 2020

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Annual Report on Form 10-K of NSTAR Electric Company (the registrant) for the period ending December 31, 2019 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, Chairman of the registrant, and Philip J. Lembo, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	Chairman

/s/	Philip J. Lembo
	Philip J. Lembo
	Executive Vice President and Chief Financial Officer

Date:  February 26, 2020

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Annual Report on Form 10-K of Public Service Company of New Hampshire (the registrant) for the period ending December 31, 2019 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, Chairman of the registrant, and Philip J. Lembo, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	Chairman

/s/	Philip J. Lembo
	Philip J. Lembo
	Executive Vice President and Chief Financial Officer

Date:  February 26, 2020

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

XML

LEASES

12 Months Ended

Dec. 31, 2019

Leases [Abstract]

LEASES

LEASES

Eversource, including CL&P, NSTAR Electric and PSNH, has entered into lease agreements as a lessee for the use of land, office space, service centers, vehicles, information technology, and equipment. These lease agreements are classified as either finance or operating leases and the liability and right-of-use asset are recognized on the balance sheet at lease commencement.  Leases with an initial term of 12 months or less are not recorded on the balance sheet and are recognized as lease expense on a straight-line basis over the lease term.

Eversource determines whether or not a contract contains a lease based on whether or not it provides Eversource with the use of a specifically identified asset for a period of time, as well as both the right to direct the use of that asset and receive the significant economic benefits of the asset. Eversource has elected the practical expedient to not separate non-lease components from lease components and instead to account for both as a single lease component, with the exception of the information technology asset class where the lease and non-lease components are separated.

The provisions of Eversource, CL&P, NSTAR Electric and PSNH lease agreements contain renewal options. The renewal options range from one year to twenty years. The renewal period is included in the measurement of the lease liability if it is reasonably certain that Eversource will exercise these renewal options.

For leases entered into or modified after the January 1, 2019 implementation date, the discount rate utilized for classification and measurement purposes as of the inception date of the lease is based on each company's collateralized incremental interest rate to borrow over a comparable term for an individual lease because the rate implicit in the lease is not determinable.

CL&P and PSNH entered into certain contracts for the purchase of energy that qualify as leases.  These contracts do not have minimum lease payments and therefore are not recognized as a lease liability on the balance sheet and are not reflected in the future minimum lease payments table below.  Expense related to these contracts is included as variable lease cost in the table below. The expense and long-term obligation for these contracts are also included in Note 13B, "Commitments and Contingencies - Long-Term Contractual Arrangements," to the financial statements.  

The components of lease cost, prior to amounts capitalized, are as follows:

	For the Year Ended December 31, 2019
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
Financing Lease Cost:
Amortization of Right-of-use-Assets	$	1.7	$	0.7	$	0.2	$	0.1
Interest on Lease Liabilities	1.2		0.6		0.6		—
Total Finance Lease Cost	2.9		1.3		0.8		0.1
Operating Lease Cost	11.7		0.5		3.4		0.1
Variable Lease Cost	60.5		13.3		—		47.2
Total Lease Cost	$	75.1	$	15.1	$	4.2	$	47.4

Operating lease rental payments charged to expense in 2018 and 2017 (which exclude CL&P's and PSNH's energy purchase contracts) were as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2018	$	10.8	$	10.9	$	11.8	$	2.5
2017	10.5		11.7		11.3		3.3

Operating lease cost, net of the capitalized portion, is included in Operations and Maintenance (or Purchased Power, Fuel and Transmission expense for transmission segment leases) on the statements of income. Amortization of finance lease assets is included in Depreciation on the statements of income. Interest expense on finance leases is included in Interest Expense on the statements of income.

Supplemental balance sheet information related to leases is as follows:

		As of December 31, 2019
(Millions of Dollars)	Balance Sheet Classification	Eversource		CL&P		NSTAR Electric		PSNH
Operating Leases:
Operating Lease Right-of-use-Assets, Net	Other Long-Term Assets	$	49.9	$	0.7	$	24.2	$	0.4
Operating Lease Liabilities
Operating Lease Liabilities - Current Portion	Other Current Liabilities	$	8.6	$	0.5	$	0.7	$	0.1
Operating Lease Liabilities - Long-Term	Other Long-Term Liabilities	41.3		0.2		23.5		0.3
Total Operating Lease Liabilities		$	49.9	$	0.7	$	24.2	$	0.4
Finance Leases:
Finance Lease Right-of-use-Assets, Net	Property, Plant and Equipment, Net	$	8.2	$	1.9	$	3.3	$	0.9
Finance Lease Liabilities
Finance Lease Liabilities - Current Portion	Other Current Liabilities	$	2.4	$	1.6	$	—	$	0.1
Finance Lease Liabilities - Long-Term	Other Long-Term Liabilities	8.1		1.4		4.4		0.8
Total Finance Lease Liabilities		$	10.5	$	3.0	$	4.4	$	0.9

The finance lease payments that NSTAR Electric will make over the next twelve months are entirely interest-related, due to escalating payments. As such, none of the finance lease payments over the next twelve months will reduce the finance lease liability.

Other information related to leases is as follows (in millions of dollars, unless otherwise noted):

	Eversource		CL&P		NSTAR Electric		PSNH
As of December 31, 2019
Weighted-Average Remaining Lease Term (Years):
Operating Leases	12		2		20		9
Finance Leases	12		2		22		9
Weighted-Average Discount Rate (Percentage):
Operating Leases	3.9	%	2.5	%	4.1	%	3.7	%
Finance Leases	4.0	%	10.5	%	2.9	%	3.5	%

	Eversource		CL&P		NSTAR Electric		PSNH
For the Year Ended December 31, 2019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$	11.4	$	0.4	$	1.6	$	0.1
Operating Cash Flows from Finance Leases	1.2		0.6		0.6		—
Financing Cash Flows from Finance Leases	2.6		1.4		—		0.1
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	2.9		1.0		0.1		0.2
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	2.0		—		—		—

Future minimum lease payments, excluding variable costs, under long-term leases, as of December 31, 2019 are as follows:

	Operating Leases								Finance Leases
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Year Ending December 31,
2020	$	10.2	$	0.5	$	1.8	$	0.1	$	3.4	$	2.0	$	0.6	$	0.1
2021	9.0		0.2		1.6		0.1		2.9		1.5		0.6		0.1
2022	7.4		—		1.6		0.1		1.5		—		0.6		0.1
2023	4.9		—		1.6		—		0.8		—		0.6		0.1
2024	2.8		—		1.7		—		0.8		—		0.7		0.1
Thereafter	28.9		0.1		28.7		0.2		13.1		—		12.6		0.5
Future lease payments	63.2		0.8		37.0		0.5		22.5		3.5		15.7		1.0
Less amount representing interest	13.3		0.1		12.8		0.1		12.0		0.5		11.3		0.1
Present value of future minimum lease payments	$	49.9	$	0.7	$	24.2	$	0.4	$	10.5	$	3.0	$	4.4	$	0.9

At December 31, 2018, future minimum rental payments, excluding executory costs, such as property taxes, state use taxes, insurance, and maintenance were as follows:

Operating Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	11.5	$	1.5	$	7.2	$	0.5
2020	9.8		1.4		6.0		0.4
2021	8.7		1.2		5.3		0.4
2022	7.2		1.1		4.4		0.4
2023	4.7		0.5		3.1		0.2
Thereafter	32.7		0.2		29.5		0.3
Future minimum lease payments	$	74.6	$	5.9	$	55.5	$	2.2

Capital Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	3.4	$	2.0	$	0.5	$	0.1
2020	3.4		2.0		0.5		0.1
2021	2.9		1.5		0.5		0.1
2022	1.5		—		0.6		0.1
2023	0.7		—		0.6		0.1
Thereafter	13.9		—		13.4		0.5
Future minimum lease payments	25.8		5.5		16.1		1.0
Less amount representing interest	13.8		1.0		12.4		0.1
Present value of future minimum lease payments	$	12.0	$	4.5	$	3.7	$	0.9

LEASES

LEASES

Eversource, including CL&P, NSTAR Electric and PSNH, has entered into lease agreements as a lessee for the use of land, office space, service centers, vehicles, information technology, and equipment. These lease agreements are classified as either finance or operating leases and the liability and right-of-use asset are recognized on the balance sheet at lease commencement.  Leases with an initial term of 12 months or less are not recorded on the balance sheet and are recognized as lease expense on a straight-line basis over the lease term.

Eversource determines whether or not a contract contains a lease based on whether or not it provides Eversource with the use of a specifically identified asset for a period of time, as well as both the right to direct the use of that asset and receive the significant economic benefits of the asset. Eversource has elected the practical expedient to not separate non-lease components from lease components and instead to account for both as a single lease component, with the exception of the information technology asset class where the lease and non-lease components are separated.

The provisions of Eversource, CL&P, NSTAR Electric and PSNH lease agreements contain renewal options. The renewal options range from one year to twenty years. The renewal period is included in the measurement of the lease liability if it is reasonably certain that Eversource will exercise these renewal options.

For leases entered into or modified after the January 1, 2019 implementation date, the discount rate utilized for classification and measurement purposes as of the inception date of the lease is based on each company's collateralized incremental interest rate to borrow over a comparable term for an individual lease because the rate implicit in the lease is not determinable.

CL&P and PSNH entered into certain contracts for the purchase of energy that qualify as leases.  These contracts do not have minimum lease payments and therefore are not recognized as a lease liability on the balance sheet and are not reflected in the future minimum lease payments table below.  Expense related to these contracts is included as variable lease cost in the table below. The expense and long-term obligation for these contracts are also included in Note 13B, "Commitments and Contingencies - Long-Term Contractual Arrangements," to the financial statements.  

The components of lease cost, prior to amounts capitalized, are as follows:

	For the Year Ended December 31, 2019
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
Financing Lease Cost:
Amortization of Right-of-use-Assets	$	1.7	$	0.7	$	0.2	$	0.1
Interest on Lease Liabilities	1.2		0.6		0.6		—
Total Finance Lease Cost	2.9		1.3		0.8		0.1
Operating Lease Cost	11.7		0.5		3.4		0.1
Variable Lease Cost	60.5		13.3		—		47.2
Total Lease Cost	$	75.1	$	15.1	$	4.2	$	47.4

Operating lease rental payments charged to expense in 2018 and 2017 (which exclude CL&P's and PSNH's energy purchase contracts) were as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2018	$	10.8	$	10.9	$	11.8	$	2.5
2017	10.5		11.7		11.3		3.3

Operating lease cost, net of the capitalized portion, is included in Operations and Maintenance (or Purchased Power, Fuel and Transmission expense for transmission segment leases) on the statements of income. Amortization of finance lease assets is included in Depreciation on the statements of income. Interest expense on finance leases is included in Interest Expense on the statements of income.

Supplemental balance sheet information related to leases is as follows:

		As of December 31, 2019
(Millions of Dollars)	Balance Sheet Classification	Eversource		CL&P		NSTAR Electric		PSNH
Operating Leases:
Operating Lease Right-of-use-Assets, Net	Other Long-Term Assets	$	49.9	$	0.7	$	24.2	$	0.4
Operating Lease Liabilities
Operating Lease Liabilities - Current Portion	Other Current Liabilities	$	8.6	$	0.5	$	0.7	$	0.1
Operating Lease Liabilities - Long-Term	Other Long-Term Liabilities	41.3		0.2		23.5		0.3
Total Operating Lease Liabilities		$	49.9	$	0.7	$	24.2	$	0.4
Finance Leases:
Finance Lease Right-of-use-Assets, Net	Property, Plant and Equipment, Net	$	8.2	$	1.9	$	3.3	$	0.9
Finance Lease Liabilities
Finance Lease Liabilities - Current Portion	Other Current Liabilities	$	2.4	$	1.6	$	—	$	0.1
Finance Lease Liabilities - Long-Term	Other Long-Term Liabilities	8.1		1.4		4.4		0.8
Total Finance Lease Liabilities		$	10.5	$	3.0	$	4.4	$	0.9

The finance lease payments that NSTAR Electric will make over the next twelve months are entirely interest-related, due to escalating payments. As such, none of the finance lease payments over the next twelve months will reduce the finance lease liability.

Other information related to leases is as follows (in millions of dollars, unless otherwise noted):

	Eversource		CL&P		NSTAR Electric		PSNH
As of December 31, 2019
Weighted-Average Remaining Lease Term (Years):
Operating Leases	12		2		20		9
Finance Leases	12		2		22		9
Weighted-Average Discount Rate (Percentage):
Operating Leases	3.9	%	2.5	%	4.1	%	3.7	%
Finance Leases	4.0	%	10.5	%	2.9	%	3.5	%

	Eversource		CL&P		NSTAR Electric		PSNH
For the Year Ended December 31, 2019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$	11.4	$	0.4	$	1.6	$	0.1
Operating Cash Flows from Finance Leases	1.2		0.6		0.6		—
Financing Cash Flows from Finance Leases	2.6		1.4		—		0.1
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	2.9		1.0		0.1		0.2
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	2.0		—		—		—

Future minimum lease payments, excluding variable costs, under long-term leases, as of December 31, 2019 are as follows:

	Operating Leases								Finance Leases
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Year Ending December 31,
2020	$	10.2	$	0.5	$	1.8	$	0.1	$	3.4	$	2.0	$	0.6	$	0.1
2021	9.0		0.2		1.6		0.1		2.9		1.5		0.6		0.1
2022	7.4		—		1.6		0.1		1.5		—		0.6		0.1
2023	4.9		—		1.6		—		0.8		—		0.6		0.1
2024	2.8		—		1.7		—		0.8		—		0.7		0.1
Thereafter	28.9		0.1		28.7		0.2		13.1		—		12.6		0.5
Future lease payments	63.2		0.8		37.0		0.5		22.5		3.5		15.7		1.0
Less amount representing interest	13.3		0.1		12.8		0.1		12.0		0.5		11.3		0.1
Present value of future minimum lease payments	$	49.9	$	0.7	$	24.2	$	0.4	$	10.5	$	3.0	$	4.4	$	0.9

At December 31, 2018, future minimum rental payments, excluding executory costs, such as property taxes, state use taxes, insurance, and maintenance were as follows:

Operating Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	11.5	$	1.5	$	7.2	$	0.5
2020	9.8		1.4		6.0		0.4
2021	8.7		1.2		5.3		0.4
2022	7.2		1.1		4.4		0.4
2023	4.7		0.5		3.1		0.2
Thereafter	32.7		0.2		29.5		0.3
Future minimum lease payments	$	74.6	$	5.9	$	55.5	$	2.2

Capital Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	3.4	$	2.0	$	0.5	$	0.1
2020	3.4		2.0		0.5		0.1
2021	2.9		1.5		0.5		0.1
2022	1.5		—		0.6		0.1
2023	0.7		—		0.6		0.1
Thereafter	13.9		—		13.4		0.5
Future minimum lease payments	25.8		5.5		16.1		1.0
Less amount representing interest	13.8		1.0		12.4		0.1
Present value of future minimum lease payments	$	12.0	$	4.5	$	3.7	$	0.9

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LEASES - Components of Lease Cost (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($)
Financing Lease Cost:
Amortization of Right-of-use-Assets	$ 1.7
Interest on Lease Liabilities	1.2
Total Finance Lease Cost	2.9
Operating Lease Cost	11.7
Variable Lease Cost	60.5
Total Lease Cost	75.1
CL&P
Financing Lease Cost:
Amortization of Right-of-use-Assets	0.7
Interest on Lease Liabilities	0.6
Total Finance Lease Cost	1.3
Operating Lease Cost	0.5
Variable Lease Cost	13.3
Total Lease Cost	15.1
NSTAR Electric
Financing Lease Cost:
Amortization of Right-of-use-Assets	0.2
Interest on Lease Liabilities	0.6
Total Finance Lease Cost	0.8
Operating Lease Cost	3.4
Variable Lease Cost	0.0
Total Lease Cost	4.2
PSNH
Financing Lease Cost:
Amortization of Right-of-use-Assets	0.1
Interest on Lease Liabilities	0.0
Total Finance Lease Cost	0.1
Operating Lease Cost	0.1
Variable Lease Cost	47.2
Total Lease Cost	$ 47.4

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LEASES - Future Minimum Lease Payments under Long-Term Leases (Details) $ in Millions	Dec. 31, 2019 USD ($)
Operating Leases
2020	$ 10.2
2021	9.0
2022	7.4
2023	4.9
2024	2.8
Thereafter	28.9
Future lease payments	63.2
Less amount representing interest	13.3
Present value of future minimum lease payments	49.9
Finance Leases
2020	3.4
2021	2.9
2022	1.5
2023	0.8
2024	0.8
Thereafter	13.1
Future lease payments	22.5
Less amount representing interest	12.0
Present value of future minimum lease payments	10.5
CL&P
Operating Leases
2020	0.5
2021	0.2
2022	0.0
2023	0.0
2024	0.0
Thereafter	0.1
Future lease payments	0.8
Less amount representing interest	0.1
Present value of future minimum lease payments	0.7
Finance Leases
2020	2.0
2021	1.5
2022	0.0
2023	0.0
2024	0.0
Thereafter	0.0
Future lease payments	3.5
Less amount representing interest	0.5
Present value of future minimum lease payments	3.0
NSTAR Electric
Operating Leases
2020	1.8
2021	1.6
2022	1.6
2023	1.6
2024	1.7
Thereafter	28.7
Future lease payments	37.0
Less amount representing interest	12.8
Present value of future minimum lease payments	24.2
Finance Leases
2020	0.6
2021	0.6
2022	0.6
2023	0.6
2024	0.7
Thereafter	12.6
Future lease payments	15.7
Less amount representing interest	11.3
Present value of future minimum lease payments	4.4
PSNH
Operating Leases
2020	0.1
2021	0.1
2022	0.1
2023	0.0
2024	0.0
Thereafter	0.2
Future lease payments	0.5
Less amount representing interest	0.1
Present value of future minimum lease payments	0.4
Finance Leases
2020	0.1
2021	0.1
2022	0.1
2023	0.1
2024	0.1
Thereafter	0.5
Future lease payments	1.0
Less amount representing interest	0.1
Present value of future minimum lease payments	$ 0.9

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COMMON SHARES

12 Months Ended

Dec. 31, 2019

Equity [Abstract]

COMMON SHARES

COMMON SHARES

The following table sets forth the Eversource parent common shares and the shares of common stock of CL&P, NSTAR Electric and PSNH that were authorized and issued, as well as the respective per share par values:  

	Shares
	Par Value		Authorized as of December 31, 2019 and 2018	Issued as of December 31,
				2019	2018
Eversource	$	5	380,000,000	345,858,402	333,878,402
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

Common Share Issuance and Forward Sale Agreement: On June 4, 2019, Eversource completed an equity offering of 17,940,000 common shares, consisting of 5,980,000 common shares issued directly by the Company and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resulted in proceeds of $426.9 million, net of issuance costs.

Under the forward sale agreement, a total of 11,960,000 common shares were borrowed from third parties and sold by the underwriters. The forward sale agreement allows Eversource, at its election and prior to May 29, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially, $71.48 per share) or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as dividends.

On December 30, 2019, Eversource physically settled a portion of the forward sale agreement by delivering 6,000,000 common shares in exchange for net proceeds of $425.4 million. The forward sale price used to determine the cash proceeds received by Eversource was calculated based on the initial forward sale price of $71.48 per share, as adjusted in accordance with the forward sale agreement.

The 2019 issuances of 11,980,000 common shares resulted in proceeds of $852.3 million, net of issuance costs, and were reflected in shareholders’ equity and as financing activities on the statement of cash flows.

Eversource’s intent is to physically settle the forward sale agreement by issuing common shares. As of December 31, 2019, if Eversource had elected to net settle the forward sale agreement, Eversource would have been required to pay $84.4 million under a cash settlement or would have been required to deliver 992,189 common shares under a net share settlement.

Issuances of shares under the forward sale agreement are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreement have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method. See Note 22, "Earnings Per Share," to the financial statements for information on the forward sale agreement’s impact on the calculation of diluted EPS.

Eversource used the net proceeds received upon the direct issuance of common shares and the net proceeds received upon partial settlement of the forward sale agreement to repay short-term debt under the commercial paper program, to fund capital spending and clean energy initiatives, and for general corporate purposes.

Treasury Shares: As of December 31, 2019 and 2018, there were 15,977,757 and 16,992,594 Eversource common shares held as treasury shares, respectively.  As of December 31, 2019 and 2018, there were 329,880,645 and 316,885,808 Eversource common shares outstanding, respectively.

Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan.

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $7.5 million for each of the years ended December 31, 2019, 2018 and 2017.  These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of December 31, 2019 and 2018.  On the Eversource balance sheets, Common Shareholders' Equity was fully attributable to Eversource parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.

For the years ended December 31, 2019, 2018 and 2017, there was no change in ownership of the common equity of CL&P and NSTAR Electric.

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INCOME TAXES - Tax Credits and Loss Carryforwards (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Internal Revenue Service (IRS)
Operating Loss Carryforwards [Line Items]
Federal and State Tax Credit	$ 19.8	$ 103.6
Federal and State Charitable Contribution	0.0	2.2
State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Federal and State Tax Credit	168.1	148.9
Federal and State Charitable Contribution	9.9	9.6
Operating Loss Carryforwards	65.5	80.7
CL&P | Internal Revenue Service (IRS)
Operating Loss Carryforwards [Line Items]
Federal and State Tax Credit	0.0	0.0
Federal and State Charitable Contribution	0.0	0.0
CL&P | State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Federal and State Tax Credit	122.3	107.0
Federal and State Charitable Contribution	0.0	0.0
Operating Loss Carryforwards	0.0	0.0
NSTAR Electric | Internal Revenue Service (IRS)
Operating Loss Carryforwards [Line Items]
Federal and State Tax Credit	0.0	0.0
Federal and State Charitable Contribution	0.0	0.0
NSTAR Electric | State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Federal and State Tax Credit	0.0	0.0
Federal and State Charitable Contribution	0.0	0.0
Operating Loss Carryforwards	0.0	0.0
PSNH | Internal Revenue Service (IRS)
Operating Loss Carryforwards [Line Items]
Federal and State Tax Credit	0.0	0.0
Federal and State Charitable Contribution	0.0	0.0
PSNH | State and Local Jurisdiction
Operating Loss Carryforwards [Line Items]
Federal and State Tax Credit	0.0	0.0
Federal and State Charitable Contribution	0.0	0.0
Operating Loss Carryforwards	$ 0.0	$ 0.0

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EMPLOYEE BENEFITS - Schedule of Other Retirement Benefits (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actuarially-Determined Liability	$ 52.0	$ 49.1	$ 53.4
Other Retirement Benefits Expense	2.7	2.7	2.8
CL&P
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actuarially-Determined Liability	0.2	0.3	0.3
Other Retirement Benefits Expense	1.0	1.1	1.0
NSTAR Electric
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actuarially-Determined Liability	0.1	0.1	0.1
Other Retirement Benefits Expense	0.9	1.1	1.0
PSNH
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Actuarially-Determined Liability	1.7	1.7	1.9
Other Retirement Benefits Expense	$ 0.4	$ 0.4	$ 0.5

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COMMITMENTS AND CONTINGENCIES - Schedule of Reconciliation of Activity in Environmental Reserve (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Accrual for Environmental Loss Contingencies [Roll Forward]
Accrual for Environmental Loss Contingencies, Beginning Balance	$ 64.7	$ 54.9
Additions	26.5	23.5
Payments/Reductions	(10.2)	(13.7)
Accrual for Environmental Loss Contingencies, Ending Balance	81.0	64.7
CL&P
Accrual for Environmental Loss Contingencies [Roll Forward]
Accrual for Environmental Loss Contingencies, Beginning Balance	5.4	4.7
Additions	7.0	1.9
Payments/Reductions	(1.0)	(1.2)
Accrual for Environmental Loss Contingencies, Ending Balance	11.4	5.4
NSTAR Electric
Accrual for Environmental Loss Contingencies [Roll Forward]
Accrual for Environmental Loss Contingencies, Beginning Balance	10.9	2.7
Additions	0.5	9.7
Payments/Reductions	(3.4)	(1.5)
Accrual for Environmental Loss Contingencies, Ending Balance	8.0	10.9
PSNH
Accrual for Environmental Loss Contingencies [Roll Forward]
Accrual for Environmental Loss Contingencies, Beginning Balance	5.4	5.7
Additions	2.8	0.0
Payments/Reductions	(0.7)	(0.3)
Accrual for Environmental Loss Contingencies, Ending Balance	$ 7.5	$ 5.4

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EMPLOYEE BENEFITS - Schedule of Funded Status (Details) - Pension Plan - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 5,963.4	$ 5,070.8
CL&P
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	1,205.4	1,031.0
NSTAR Electric
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	1,340.8	1,144.7
PSNH
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 646.7	$ 543.1

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Restricted Cash and Cash Equivalents Items [Line Items]
Cash	$ 15,432	$ 108,068
Cash and Restricted Cash reported on the Statements of Cash Flows	117,063	209,324	$ 85,890	$ 106,750
CL&P
Restricted Cash and Cash Equivalents Items [Line Items]
Cash	0	87,721
Cash and Restricted Cash reported on the Statements of Cash Flows	4,971	91,613	9,619	8,403
NSTAR Electric
Restricted Cash and Cash Equivalents Items [Line Items]
Cash	52	1,606
Cash and Restricted Cash reported on the Statements of Cash Flows	6,312	14,659	14,708	15,507
PSNH
Restricted Cash and Cash Equivalents Items [Line Items]
Cash	413	1,439
Cash and Restricted Cash reported on the Statements of Cash Flows	36,688	52,723	$ 2,191	$ 5,953
Prepayments and Other Current Assets
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	52,500	72,100
Prepayments and Other Current Assets | CL&P
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	4,600	3,500
Prepayments and Other Current Assets | NSTAR Electric
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	6,200	13,000
Prepayments and Other Current Assets | PSNH
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash		47,500
Marketable Securities
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	46,000	25,900
Marketable Securities | CL&P
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	400	400
Marketable Securities | NSTAR Electric
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	0	100
Marketable Securities | PSNH
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	600	600
Other Long-Term Assets
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	3,200	3,200
Other Long-Term Assets | CL&P
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	0	0
Other Long-Term Assets | NSTAR Electric
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 0	0
Other Long-Term Assets | PSNH
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash		$ 3,200

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LONG-TERM DEBT - Schedule of Long-Term Debt Outstanding (Details) - USD ($)	Dec. 31, 2019	Dec. 31, 2018	Dec. 08, 2017
Debt Instrument [Line Items]
Long-Term Debt	$ 13,770,828,000	$ 12,248,743,000
Less Amounts due in One Year	(327,411,000)	(837,319,000)
Senior Notes
Debt Instrument [Line Items]
Unamortized Premiums and Discounts, Net	(4,100,000)	(4,200,000)
Unamortized Debt Issuance Costs	(20,600,000)	(23,200,000)
Long-term debt	13,770,800,000	12,248,700,000
Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)
Debt Instrument [Line Items]
Long-Term Debt	11,600,000	39,500,000
Fair Value Adjustment
Debt Instrument [Line Items]
Long-Term Debt	109,100,000	144,700,000
Fair Value Adjustment - Current Portion
Debt Instrument [Line Items]
Long-Term Debt	(31,300,000)	(36,200,000)
Loans Payable
Debt Instrument [Line Items]
Less Amounts due in One Year	(201,100,000)	(401,100,000)
Total Other Long-Term Debt
Debt Instrument [Line Items]
Long-Term Debt	6,054,000,000.0	5,644,700,000
CL&P
Debt Instrument [Line Items]
Long-Term Debt	3,518,136,000	3,004,016,000
Less Amounts due in One Year	0	(250,000,000)
CL&P | 4.375% Fixed Rate Tax Exempt due 2028
Debt Instrument [Line Items]
Long-Term Debt	120,500,000	120,500,000
CL&P | First Mortgage Bonds:
Debt Instrument [Line Items]
Long-Term Debt	3,394,800,000	3,144,800,000
Unamortized Premiums and Discounts, Net	27,800,000	10,200,000
Unamortized Debt Issuance Costs	(25,000,000.0)	(21,500,000)
Long-term debt	$ 3,518,100,000	3,004,000,000.0
CL&P | First Mortgage Bonds: | 7.875% 1994 Series D due 2024
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	7.875%
Long-Term Debt	$ 139,800,000	139,800,000
CL&P | First Mortgage Bonds: | 5.750% 2004 Series B due 2034
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.75%
Long-Term Debt	$ 130,000,000.0	130,000,000.0
CL&P | First Mortgage Bonds: | 5.625% 2005 Series B due 2035
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.625%
Long-Term Debt	$ 100,000,000.0	100,000,000.0
CL&P | First Mortgage Bonds: | 6.350% 2006 Series A due 2036
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	6.35%
Long-Term Debt	$ 250,000,000.0	250,000,000.0
CL&P | First Mortgage Bonds: | 5.750% 2007 Series B due 2037
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.75%
Long-Term Debt	$ 150,000,000.0	150,000,000.0
CL&P | First Mortgage Bonds: | 6.375% 2007 Series D due 2037
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	6.375%
Long-Term Debt	$ 100,000,000.0	100,000,000.0
CL&P | First Mortgage Bonds: | 5.500% 2009 Series A due 2019
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.50%
Long-Term Debt	$ 0	250,000,000.0
CL&P | First Mortgage Bonds: | 2.500% 2013 Series A due 2023
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	2.50%
Long-Term Debt	$ 400,000,000.0	400,000,000.0
CL&P | First Mortgage Bonds: | 4.300% 2014 Series A due 2044
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.30%
Long-Term Debt	$ 475,000,000.0	475,000,000.0
CL&P | First Mortgage Bonds: | 4.150% 2015 Series A due 2045
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.15%
Long-Term Debt	$ 350,000,000.0	350,000,000.0
CL&P | First Mortgage Bonds: | 3.200% 2017 Series A due 2027
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.20%
Long-Term Debt	$ 500,000,000.0	300,000,000.0
CL&P | First Mortgage Bonds: | 4.000% 2018 Series A due 2048
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.00%
Long-Term Debt	$ 800,000,000.0	500,000,000.0
NSTAR Electric
Debt Instrument [Line Items]
Long-Term Debt	3,247,086,000	2,944,846,000
Less Amounts due in One Year	(95,000,000)	0
NSTAR Electric | Unsecured Debt
Debt Instrument [Line Items]
Long-Term Debt	2,800,000,000.0	2,400,000,000.0
Less Amounts due in One Year	(95,000,000.0)	0
Unamortized Premiums and Discounts, Net	(4,100,000)	(2,500,000)
Unamortized Debt Issuance Costs	(18,800,000)	(17,700,000)
Long-term debt	$ 3,247,100,000	2,944,800,000
NSTAR Electric | Unsecured Debt | 5.750% due 2036
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.75%
Long-Term Debt	$ 200,000,000.0	200,000,000.0
NSTAR Electric | Unsecured Debt | 5.500% due 2040
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.50%
Long-Term Debt	$ 300,000,000.0	300,000,000.0
NSTAR Electric | Unsecured Debt | 2.375% due 2022
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	2.375%
Long-Term Debt	$ 400,000,000.0	400,000,000.0
NSTAR Electric | Unsecured Debt | 4.400% due 2044
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.40%
Long-Term Debt	$ 300,000,000.0	300,000,000.0
NSTAR Electric | Unsecured Debt | 3.250% due 2025
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.25%
Long-Term Debt	$ 250,000,000.0	250,000,000.0
NSTAR Electric | Unsecured Debt | 2.700% due 2026
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	2.70%
Long-Term Debt	$ 250,000,000.0	250,000,000.0
NSTAR Electric | Unsecured Debt | 3.200% due 2027
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.20%
Long-Term Debt	$ 700,000,000.0	700,000,000.0
NSTAR Electric | Unsecured Debt | 3.250% due 2029
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.25%
Long-Term Debt	$ 400,000,000.0	0
NSTAR Electric | Senior Notes
Debt Instrument [Line Items]
Long-Term Debt	$ 565,000,000.0	565,000,000.0
NSTAR Electric | Senior Notes | 5.900% Senior Notes Series B due 2034
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.90%
Long-Term Debt	$ 50,000,000.0	50,000,000.0
NSTAR Electric | Senior Notes | 6.700% Senior Notes Series D due 2037
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	6.70%
Long-Term Debt	$ 40,000,000.0	40,000,000.0
NSTAR Electric | Senior Notes | 5.100% Senior Notes Series E due 2020
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.10%
Long-Term Debt	$ 95,000,000.0	95,000,000.0
NSTAR Electric | Senior Notes | 3.500% Senior Notes Series F due 2021
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.50%
Long-Term Debt	$ 250,000,000.0	250,000,000.0
NSTAR Electric | Senior Notes | 3.880% Senior Notes Series G due 2023
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.88%
Long-Term Debt	$ 80,000,000.0	80,000,000.0
NSTAR Electric | Senior Notes | 2.750% Senior Notes Series H due 2026
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	2.75%
Long-Term Debt	$ 50,000,000.0	50,000,000.0
PSNH
Debt Instrument [Line Items]
Long-Term Debt	951,620,000	655,173,000
Less Amounts due in One Year	0	(150,000,000)
PSNH | First Mortgage Bonds:
Debt Instrument [Line Items]
Long-Term Debt	957,000,000.0	807,000,000.0
Less Amounts due in One Year	0	(150,000,000.0)
Unamortized Premiums and Discounts, Net	(700,000)	0
Unamortized Debt Issuance Costs	(4,700,000)	(1,800,000)
Long-term debt	$ 951,600,000	655,200,000
PSNH | First Mortgage Bonds: | 5.600% Series M due 2035
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	5.60%
Long-Term Debt	$ 50,000,000.0	50,000,000.0
PSNH | First Mortgage Bonds: | 4.500% Series P due 2019
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.50%
Long-Term Debt	$ 0	150,000,000.0
PSNH | First Mortgage Bonds: | 4.050% Series Q due 2021
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.05%
Long-Term Debt	$ 122,000,000.0	122,000,000.0
PSNH | First Mortgage Bonds: | 3.200% Series R due 2021
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.20%
Long-Term Debt	$ 160,000,000.0	160,000,000.0
PSNH | First Mortgage Bonds: | 3.500% Series S due 2023
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.50%
Long-Term Debt	$ 325,000,000.0	325,000,000.0
PSNH | First Mortgage Bonds: | 3.600% Series T due 2049
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.60%
Long-Term Debt	$ 300,000,000.0	0
Yankee Gas | First Mortgage Bonds: | Yankee Gas - First Mortgage Bonds: 2.230% - 8.480% due 2020 - 2049
Debt Instrument [Line Items]
Long-Term Debt	620,000,000.0	470,000,000.0
NSTAR Gas | First Mortgage Bonds: | NSTAR Gas - First Mortgage Bonds: 3.740% - 9.950% due 2020 - 2049
Debt Instrument [Line Items]
Long-Term Debt	$ 460,000,000.0	385,000,000.0
Aquarion | Unsecured Debt | Aquarion - Senior Note 4.000% due 2024
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.00%
Long-Term Debt	$ 360,000,000.0	360,000,000.0
Aquarion | Unsecured Debt | Aquarion - Unsecured Notes 0% - 6.430% due 2021 - 2049
Debt Instrument [Line Items]
Long-Term Debt	335,300,000	289,500,000
Aquarion | Unsecured Debt | Aquarion - Secured Debt 4.100% - 9.640% due 2021 - 2035
Debt Instrument [Line Items]
Long-Term Debt	68,800,000	70,700,000
Commercial Paper
Debt Instrument [Line Items]
Commercial Paper Classified as Long-Term Debt (See Note 8, Short-Term Debt)	346,300,000	0
Commercial Paper | NSTAR Electric
Debt Instrument [Line Items]
Commercial Paper Classified as Long-Term Debt (See Note 8, Short-Term Debt)	$ 650,000,000
Minimum | Yankee Gas | First Mortgage Bonds: | Yankee Gas - First Mortgage Bonds: 2.230% - 8.480% due 2020 - 2049
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	2.23%
Minimum | NSTAR Gas | First Mortgage Bonds: | NSTAR Gas - First Mortgage Bonds: 3.740% - 9.950% due 2020 - 2049
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	3.74%
Minimum | Aquarion | Unsecured Debt | Aquarion - Unsecured Notes 0% - 6.430% due 2021 - 2049
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	0.00%
Minimum | Aquarion | Unsecured Debt | Aquarion - Secured Debt 4.100% - 9.640% due 2021 - 2035
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.10%
Maximum | Yankee Gas | First Mortgage Bonds: | Yankee Gas - First Mortgage Bonds: 2.230% - 8.480% due 2020 - 2049
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	8.48%
Maximum | NSTAR Gas | First Mortgage Bonds: | NSTAR Gas - First Mortgage Bonds: 3.740% - 9.950% due 2020 - 2049
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	9.95%
Maximum | Aquarion | Unsecured Debt | Aquarion - Unsecured Notes 0% - 6.430% due 2021 - 2049
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	6.43%
Maximum | Aquarion | Unsecured Debt | Aquarion - Secured Debt 4.100% - 9.640% due 2021 - 2035
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	9.64%
Eversource
Debt Instrument [Line Items]
Long-Term Debt	$ 4,358,339,000	4,031,997,000
Less Amounts due in One Year	$ (23,933,000)	(378,883,000)
Eversource | Unsecured Debt | Eversource Parent - Debentures 4.500% due 2019
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.50%
Long-Term Debt	$ 0	350,000,000.0
Eversource | Unsecured Debt | Eversource Parent - Senior Notes 2.500% - 4.250% due 2021 - 2029
Debt Instrument [Line Items]
Long-Term Debt	4,000,000,000.0	$ 4,000,000,000.0
Eversource | Commercial Paper
Debt Instrument [Line Items]
Commercial Paper Classified as Long-Term Debt (See Note 8, Short-Term Debt)	$ 1,450,000,000		$ 1,450,000,000
Eversource | Minimum | Unsecured Debt | Eversource Parent - Senior Notes 2.500% - 4.250% due 2021 - 2029
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	2.50%
Eversource | Maximum | Unsecured Debt | Eversource Parent - Senior Notes 2.500% - 4.250% due 2021 - 2029
Debt Instrument [Line Items]
Interest rate stated percentage (up to) (as a percentage)	4.25%

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Narrative (Details) $ / shares in Units, $ in Thousands, customer in Millions		3 Months Ended	12 Months Ended
	Feb. 26, 2020 USD ($)	Jun. 30, 2019 USD ($)	Dec. 31, 2019 USD ($) utility customer $ / shares MW	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)	Jan. 01, 2019 USD ($)
Summary of Accounting Policies [Line Items]
Number of electric and natural gas customers | customer			4,000,000
Increase to operating cash inflows in accounts payable			$ (14,866)	$ (24,481)	$ (56,067)
Increase to investing cash outflows in investments in property, plant and equipment			2,911,489	2,569,936	2,348,105
Goodwill			4,427,266	4,427,266
Operating lease liabilities			49,900
Operating lease right-of-use-assets			49,900
Pre-tax impairment charge		$ 239,600	239,644	0	0
After-tax impact of impairment charge			$ 204,400
After-tax impact of impairment charge (in dollars per share) | $ / shares			$ 0.64
Columbia Gas of Massachusetts (CMA) | Subsequent Event
Summary of Accounting Policies [Line Items]
Purchase price	$ 1,100,000
CL&P
Summary of Accounting Policies [Line Items]
Increase to operating cash inflows in accounts payable			$ (102,344)	76,924	(48,032)
Increase to investing cash outflows in investments in property, plant and equipment			917,532	864,136	824,383
Operating lease liabilities			700
Operating lease right-of-use-assets			$ 700
Period of accounts receivable recoverable under financial or medical duress			180 days
Transfer of loans receivable				41,300
Maximum loans receivable outstanding			$ 55,000
Loans transferred receivable current			16,500	18,500
Loans transferred receivable non-current			18,200	22,800
Long term receivable			$ 25,000	25,000
Term of energy efficiency customer loans			3 years
Yankee Gas Services Company
Summary of Accounting Policies [Line Items]
Period of accounts receivable recoverable under financial or medical duress			90 days
NSTAR Electric
Summary of Accounting Policies [Line Items]
Increase to operating cash inflows in accounts payable			$ 22,659	(37,140)	20,421
Increase to investing cash outflows in investments in property, plant and equipment			861,391	725,766	719,623
Operating lease liabilities			24,200
Operating lease right-of-use-assets			24,200
Long term receivable			5,500	5,500
PSNH
Summary of Accounting Policies [Line Items]
Increase to operating cash inflows in accounts payable			(12,281)	10,147	(29,453)
Increase to investing cash outflows in investments in property, plant and equipment			308,993	323,910	$ 312,720
Operating lease liabilities			400
Operating lease right-of-use-assets			400
Long term receivable			$ 3,800	3,800
Connecticut, Massachusetts and New Hampshire
Summary of Accounting Policies [Line Items]
Number of regulated utilities | utility			8
Northern Pass
Summary of Accounting Policies [Line Items]
Capacity required for transmission line | MW			1,090
Capitalized costs			$ 318,000
Accounting Standards Update 2016-02
Summary of Accounting Policies [Line Items]
Operating lease liabilities						$ 58,000
Operating lease right-of-use-assets						58,000
Accounting Standards Update 2016-02 | CL&P
Summary of Accounting Policies [Line Items]
Operating lease liabilities						600
Operating lease right-of-use-assets						600
Accounting Standards Update 2016-02 | NSTAR Electric
Summary of Accounting Policies [Line Items]
Operating lease liabilities						25,300
Operating lease right-of-use-assets						25,300
Accounting Standards Update 2016-02 | PSNH
Summary of Accounting Policies [Line Items]
Operating lease liabilities						600
Operating lease right-of-use-assets						$ 600
Restatement Adjustment
Summary of Accounting Policies [Line Items]
Increase to operating cash inflows in accounts payable				(46,600)
Increase to investing cash outflows in investments in property, plant and equipment				46,600
Restatement Adjustment | PSNH
Summary of Accounting Policies [Line Items]
Increase to operating cash inflows in accounts payable				(46,600)
Increase to investing cash outflows in investments in property, plant and equipment				$ 46,600

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of AFUDC and Weighted Average AFUDC (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Components of Other Operating Costs and Expense [Line Items]
Borrowed Funds	$ 25.6	$ 19.7	$ 12.5
Equity Funds	45.0	44.0	34.4
Total AFUDC	$ 70.6	$ 63.7	$ 46.9
Average AFUDC Rate	5.40%	4.90%	5.10%
CL&P
Components of Other Operating Costs and Expense [Line Items]
Borrowed Funds	$ 7.1	$ 6.3	$ 5.1
Equity Funds	13.2	12.2	12.1
Total AFUDC	$ 20.3	$ 18.5	$ 17.2
Average AFUDC Rate	6.30%	5.80%	6.20%
NSTAR Electric
Components of Other Operating Costs and Expense [Line Items]
Borrowed Funds	$ 10.4	$ 7.8	$ 4.8
Equity Funds	19.8	15.6	10.2
Total AFUDC	$ 30.2	$ 23.4	$ 15.0
Average AFUDC Rate	5.70%	5.00%	5.00%
PSNH
Components of Other Operating Costs and Expense [Line Items]
Borrowed Funds	$ 2.8	$ 1.3	$ 0.7
Equity Funds	3.4	0.0	0.0
Total AFUDC	$ 6.2	$ 1.3	$ 0.7
Average AFUDC Rate	4.60%	0.70%	0.70%

XML

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES - Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	$ 5,514,700	$ 5,145,900
Regulatory Liabilities	3,658,042	3,609,475
Accrued Interest (included in Other Current Liabilities)	836,834	823,006
Rate Reduction Bonds - Current Portion	43,210	52,332
Rate Reduction Bonds - Long-Term Portion	540,122	583,331
Securitized Stranded Costs
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	565,300	608,400
Other Regulatory Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	125,400	208,000
PSNH
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	945,800	929,500
Regulatory Liabilities	413,381	428,069
Accrued Interest (included in Other Current Liabilities)	32,736	44,093
Rate Reduction Bonds - Current Portion	43,210	52,332
Rate Reduction Bonds - Long-Term Portion	540,122	583,331
PSNH | Securitized Stranded Costs
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	565,300	608,400
PSNH | Other Regulatory Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	14,700	12,100
Variable Interest Entity, Primary Beneficiary | PSNH
Condensed Balance Sheet Statements, Captions [Line Items]
Rate Reduction Bonds - Current Portion	43,200	52,300
Rate Reduction Bonds - Long-Term Portion	540,100	583,300
Variable Interest Entity, Primary Beneficiary | PSNH | Securitized Stranded Costs
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	565,300	608,400
Variable Interest Entity, Primary Beneficiary | PSNH | Other Regulatory Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Regulatory Liabilities	5,600	5,800
Accrued Interest (included in Other Current Liabilities)	8,600	14,400
Prepayments and Other Current Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	52,500	72,100
Prepayments and Other Current Assets | PSNH
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash		47,500
Prepayments and Other Current Assets | Variable Interest Entity, Primary Beneficiary | PSNH
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	32,500	47,500
Other Long-Term Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	3,200	3,200
Other Long-Term Assets | PSNH
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash		3,200
Other Long-Term Assets | Variable Interest Entity, Primary Beneficiary | PSNH
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	$ 3,200	$ 3,200

XML

SCHEDULE I - FINANCIAL INFORMATION OF REGISTRANT - BALANCE SHEET (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Current Assets:
Cash	$ 15,432	$ 108,068
Prepayments and Other Current Assets	342,135	260,995
Total Current Assets	2,414,539	2,292,224
Deferred Debits and Other Assets:
Investments in Subsidiary Companies, at Equity	871,633	464,286
Goodwill	4,427,266	4,427,266
Other Long-Term Assets	512,238	398,407
Total Deferred Debits and Other Assets	11,123,906	10,338,604
Total Assets	41,123,915	38,241,256
Current Liabilities:
Notes Payable	889,084	910,000
Long-Term Debt – Current Portion	327,411	837,319
Other Current Liabilities	836,834	823,006
Total Current Liabilities	3,605,563	4,112,882
Total Deferred Credits and Other Liabilities	10,421,838	9,653,913
Capitalization:
Long-Term Debt	13,770,828	12,248,743
Common Shareholders' Equity:
Common Shares	1,729,292	1,669,392
Capital Surplus, Paid in	7,087,768	6,241,222
Retained Earnings	4,177,048	3,953,974
Accumulated Other Comprehensive Loss	(65,059)	(60,000)
Treasury Stock	(299,055)	(317,771)
Common Shareholders' Equity	12,629,994	11,486,817	$ 11,086,242	$ 10,711,734
Total Liabilities and Capitalization	41,123,915	38,241,256
Eversource
Current Assets:
Cash	1,469	591	$ 521	$ 93
Accounts Receivable from Subsidiaries	25,070	32,175
Notes Receivable from Subsidiaries	1,376,000	991,400
Prepayments and Other Current Assets	33,546	26,861
Total Current Assets	1,436,085	1,051,027
Deferred Debits and Other Assets:
Investments in Subsidiary Companies, at Equity	13,162,337	12,009,659
Notes Receivable from Subsidiaries	157,000	323,500
Accumulated Deferred Income Taxes	27,578	40,454
Goodwill	3,231,811	3,231,811
Other Long-Term Assets	92,394	73,669
Total Deferred Debits and Other Assets	16,671,120	15,679,093
Total Assets	18,107,205	16,730,120
Current Liabilities:
Notes Payable	878,584	631,500
Long-Term Debt – Current Portion	23,933	378,883
Accounts Payable to Subsidiaries	4,333	8,432
Other Current Liabilities	62,385	57,877
Total Current Liabilities	969,235	1,076,692
Total Deferred Credits and Other Liabilities	149,637	134,614
Capitalization:
Long-Term Debt	4,358,339	4,031,997
Common Shareholders' Equity:
Common Shares	1,729,292	1,669,392
Capital Surplus, Paid in	7,087,768	6,241,222
Retained Earnings	4,177,048	3,953,974
Accumulated Other Comprehensive Loss	(65,059)	(60,000)
Treasury Stock	(299,055)	(317,771)
Common Shareholders' Equity	12,629,994	11,486,817
Total Liabilities and Capitalization	$ 18,107,205	$ 16,730,120

XML

EMPLOYEE BENEFITS (Tables)

12 Months Ended

Dec. 31, 2019

Postemployment Benefits [Abstract]

Schedule of Benefit Obligations in Excess of Fair Value of Plan Assets

	PBOP
	As of December 31,
	2019												2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Change in Benefit Obligation:
Benefit Obligation as of Beginning of Year	$	(841.5	)	$	(161.7	)	$	(246.3	)	$	(91.9	)	$	(948.6	)	$	(178.4	)	$	(278.6	)	$	(101.1	)
Service Cost	(7.8		)	(1.4		)	(1.7		)	(0.7		)	(10.0		)	(1.9		)	(2.0		)	(1.1		)
Interest Cost	(32.7		)	(6.3		)	(9.5		)	(3.4		)	(30.7		)	(5.8		)	(8.7		)	(3.4		)
Actuarial Gain/(Loss)	(67.0		)	(13.4		)	(15.2		)	(3.1		)	102.5			14.4			28.4			8.6
Benefits Paid	50.0			10.8			15.4			5.6			45.3			10.1			14.5			4.9
Employee Transfers	—			(0.7		)	(1.0		)	0.5			—			(0.1		)	0.1			0.2
Benefit Obligation as of End of Year	$	(899.0	)	$	(172.7	)	$	(258.3	)	$	(93.0	)	$	(841.5	)	$	(161.7	)	$	(246.3	)	$	(91.9	)
Change in Plan Assets:
Fair Value of Plan Assets as of Beginning of Year	$	849.6		$	120.6		$	379.1		$	71.2		$	922.2		$	135.9		$	405.5		$	79.0
Actual Return on Plan Assets	127.0			17.1			57.0			10.0			(36.6		)	(5.2		)	(17.4		)	(2.9		)
Employer Contributions	9.3			—			6.0			—			9.3			—			5.2			—
Benefits Paid	(50.0		)	(10.8		)	(15.4		)	(5.6		)	(45.3		)	(10.1		)	(14.5		)	(4.9		)
Employee Transfers	—			(0.6		)	(2.3		)	0.4			—			—			0.3			—
Fair Value of Plan Assets as of End of Year	$	935.9		$	126.3		$	424.4		$	76.0		$	849.6		$	120.6		$	379.1		$	71.2
Funded Status as of December 31st	$	36.9		$	(46.4	)	$	166.1		$	(17.0	)	$	8.1		$	(41.1	)	$	132.8		$	(20.7	)

The following tables provide information on the plan benefit obligations, fair values of plan assets, and funded status:  

	Pension and SERP
	As of December 31,
	2019												2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Change in Benefit Obligation:
Benefit Obligation as of Beginning of Year	$	(5,520.0	)	$	(1,160.4	)	$	(1,236.5	)	$	(610.7	)	$	(5,936.5	)	$	(1,275.2	)	$	(1,351.0	)	$	(642.2	)
Service Cost	(67.7		)	(18.0		)	(14.6		)	(7.1		)	(84.8		)	(21.4		)	(17.4		)	(11.2		)
Interest Cost	(219.0		)	(45.7		)	(49.0		)	(24.0		)	(196.4		)	(41.8		)	(43.5		)	(22.0		)
Actuarial Gain/(Loss)	(815.3		)	(176.6		)	(181.0		)	(84.5		)	414.9			106.1			98.6			39.2
Benefits Paid - Pension	273.0			60.2			67.1			30.3			261.8			59.6			66.9			26.2
Benefits Paid - Lump Sum	20.0			—			12.9			—			14.2			—			7.1			—
Benefits Paid - SERP	7.3			0.3			0.1			0.4			6.8			0.3			0.3			0.2
Employee Transfers	—			8.9			3.7			3.0			—			12.0			2.5			(0.9		)
Benefit Obligation as of End of Year	$	(6,321.7	)	$	(1,331.3	)	$	(1,397.3	)	$	(692.6	)	$	(5,520.0	)	$	(1,160.4	)	$	(1,236.5	)	$	(610.7	)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of   Beginning of Year	$	4,573.9		$	918.4		$	1,222.1		$	506.6		$	4,739.5		$	963.0		$	1,260.8		$	539.5
Employer Contributions	112.5			24.0			0.4			15.4			185.6			41.2			56.5			—
Actual Return on Pension Plan Assets	575.2			112.9			150.0			62.9			(75.2		)	(14.2		)	(18.7		)	(7.6		)
Benefits Paid - Pension	(273.0		)	(60.2		)	(67.1		)	(30.3		)	(261.8		)	(59.6		)	(66.9		)	(26.2		)
Benefits Paid - Lump Sum	(20.0		)	—			(12.9		)	—			(14.2		)	—			(7.1		)	—
Employee Transfers	—			(8.9		)	(3.7		)	(3.0		)	—			(12.0		)	(2.5		)	0.9
Fair Value of Pension Plan Assets as of End of Year	$	4,968.6		$	986.2		$	1,288.8		$	551.6		$	4,573.9		$	918.4		$	1,222.1		$	506.6
Funded Status as of December 31st	$	(1,353.1	)	$	(345.1	)	$	(108.5	)	$	(141.0	)	$	(946.1	)	$	(242.0	)	$	(14.4	)	$	(104.1	)

Schedule of Defined Benefit Plans

As of December 31, 2019 and 2018, the accumulated benefit obligation for the Pension and SERP Plans is as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	5,963.4	$	1,205.4	$	1,340.8	$	646.7
2018	5,070.8		1,031.0		1,144.7		543.1

Schedule of Assumptions Used

The following actuarial assumptions were used in calculating the Pension, SERP and PBOP Plans' year end funded status:

	Pension and SERP							PBOP
	As of December 31,							As of December 31,
		2019			2018			2019			2018
Discount Rate		3.04%	—	3.35%	4.22%	—	4.45%	3.26%	—	3.28%	4.38%	—	4.41%
Compensation/Progression Rate		3.50%	—	4.00%	3.50%	—	4.00%	N/A

The following actuarial assumptions were used to calculate Pension, SERP and PBOP expense amounts:

	Pension and SERP									PBOP
	For the Years Ended December 31,									For the Years Ended December 31,
	2019			2018			2017			2019			2018			2017
Discount Rate	2.63%	—	3.55%	3.85%	—	4.62%	3.20%	—	3.90%	3.85%	—	4.65%	3.28%	—	3.94%	3.48%	—	4.64%
Expected Long-Term Rate of Return	8.25%			8.25%			8.25%			8.25%			8.25%			8.25%
Compensation/Progression Rate	3.50%	—	4.00%	3.50%	—	4.00%	3.50%			N/A			N/A			N/A

Schedule of Net Benefit Costs

The components of net periodic benefit expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets for future recovery, are shown below. The service cost component of net periodic benefit expense/(income), less the capitalized portion, is included in Operations and Maintenance expense on the statements of income.  The remaining components of net periodic benefit expense/(income), less the deferred portion, are included in Other Income, Net on the statements of income.  Pension, SERP and PBOP expense reflected in the statements of cash flows for CL&P, NSTAR Electric and PSNH does not include the intercompany allocations or the corresponding capitalized and deferred portion, as these amounts are cash settled on a short-term basis.

	Pension and SERP												PBOP
	For the Year Ended December 31, 2019												For the Year Ended December 31, 2019
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	67.7		$	18.0		$	14.6		$	7.1		$	7.8		$	1.4		$	1.7		$	0.7
Interest Cost	219.0			45.7			49.0			24.0			32.7			6.3			9.5			3.4
Expected Return on Plan Assets	(367.1		)	(73.2		)	(97.1		)	(40.7		)	(66.8		)	(9.2		)	(30.2		)	(5.4		)
Actuarial Loss	143.2			26.9			44.7			10.6			8.3			1.3			3.3			0.3
Prior Service Cost/(Credit)	0.9			—			0.3			—			(23.5		)	1.1			(16.9		)	0.4
Total Net Periodic Benefit Expense/(Income)	$	63.7		$	17.4		$	11.5		$	1.0		$	(41.5	)	$	0.9		$	(32.6	)	$	(0.6	)
Intercompany Allocations	N/A			$	8.5		$	8.0		$	2.3		N/A			$	(0.9	)	$	(1.2	)	$	(0.4	)

	Pension and SERP												PBOP
	For the Year Ended December 31, 2018												For the Year Ended December 31, 2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	84.8		$	21.4		$	17.4		$	11.2		$	10.0		$	1.9		$	2.0		$	1.1
Interest Cost	196.4			41.8			43.5			22.0			30.7			5.8			8.7			3.4
Expected Return on Plan Assets	(391.6		)	(79.1		)	(104.9		)	(43.6		)	(72.4		)	(10.4		)	(32.5		)	(6.0		)
Actuarial Loss	145.7			29.1			41.1			11.6			10.3			1.6			2.3			0.7
Prior Service Cost/(Credit)	4.3			1.1			0.2			0.4			(23.6		)	1.1			(16.9		)	0.5
Total Net Periodic Benefit Expense/(Income)	$	39.6		$	14.3		$	(2.7	)	$	1.6		$	(45.0	)	$	—		$	(36.4	)	$	(0.3	)
Intercompany Allocations	N/A			$	6.1		$	6.5		$	1.9		N/A			$	(1.0	)	$	(1.3	)	$	(0.4	)

	Pension and SERP												PBOP
	For the Year Ended December 31, 2017												For the Year Ended December 31, 2017
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	71.3		$	18.5		$	15.5		$	9.7		$	9.5		$	1.9		$	1.7		$	1.3
Interest Cost	188.0			41.6			42.7			21.2			27.1			5.3			8.7			3.0
Expected Return on Plan Assets	(334.1		)	(71.7		)	(87.6		)	(40.0		)	(63.7		)	(9.7		)	(28.6		)	(5.5		)
Actuarial Loss	135.2			27.7			41.1			11.6			9.1			1.0			3.4			0.6
Prior Service Cost/(Credit)	4.5			1.5			0.6			0.5			(21.6		)	1.1			(17.0		)	0.6
Total Net Periodic Benefit Expense/(Income)	$	64.9		$	17.6		$	12.3		$	3.0		$	(39.6	)	$	(0.4	)	$	(31.8	)	$	—
Intercompany Allocations	N/A			$	9.8		$	9.1		$	3.3		N/A			$	(0.7	)	$	(1.1	)	$	(0.5	)

Schedule of Amounts Recognized in Regulatory Assets and OCI

The following is a summary of the changes in plan assets and benefit obligations recognized in Regulatory Assets and Other Comprehensive Income (OCI) as well as amounts in Regulatory Assets and OCI that were reclassified as net periodic benefit expense during the years presented:

	Pension and SERP												PBOP
	Regulatory Assets						OCI						Regulatory Assets						OCI
	For the Years Ended December 31,												For the Years Ended December 31,
(Millions of Dollars)	2019			2018			2019			2018			2019			2018			2019			2018
Actuarial Losses/(Gains) Arising During the Year	$	591.6		$	48.6		$	15.4		$	0.7		$	4.6		$	6.4		$	2.3		$	(1.2	)
Actuarial Losses Reclassified as Net Periodic Benefit Expense	(137.8		)	(140.1		)	(5.4		)	(5.6		)	(8.0		)	(9.9		)	(0.3		)	(0.4		)
Actuarial Losses Securitized as Stranded Costs (1)	—			(36.7		)	—			—			—			(0.8		)	—			—
Prior Service Cost Arising During the Year	—			—			—			—			—			1.3			—			—
Prior Service (Cost)/Credit Reclassified as Net Periodic Benefit (Expense)/Income	(0.7		)	(3.9		)	(0.2		)	(0.4		)	25.1			23.6			(1.6		)	—
Prior Service Cost Securitized as Stranded Costs (1)	—			(0.1		)	—			—			—			(1.3		)	—			—

⁽¹⁾ These amounts were reclassified to securitized regulatory assets in connection with the divestiture of PSNH's generation business. For further information see Note 2, "Regulatory Accounting" to the financial statements.

The following is a summary of the remaining Regulatory Assets and Accumulated Other Comprehensive Income amounts that have not been recognized as components of net periodic benefit expense as of December 31, 2019 and 2018, as well as the amounts that are expected to be recognized as components in 2020:

	Regulatory Assets as of December 31,						Expected 2020 Expense/(Income)			AOCI as of December 31,				Expected 2020 Expense
(Millions of Dollars)	2019			2018						2019		2018
Pension and SERP
Actuarial Loss	$	2,261.4		$	1,807.6		$	190.3		$	90.8	$	80.8	$	7.2
Prior Service Cost	5.6			6.3			0.9			0.9		1.1		0.2
PBOP
Actuarial Loss	$	203.9		$	207.3		$	8.3		$	7.0	$	5.0	$	0.2
Prior Service (Credit)/Cost	(172.5		)	(197.6		)	(21.4		)	1.0		2.6		0.2

Schedule of Expected Benefit Payments

The following benefit payments, which reflect expected future service, are expected to be paid by the Pension, SERP and PBOP Plans:

(Millions of Dollars)	2020		2021		2022		2023		2024		2025 - 2029
Pension and SERP	$	320.1	$	328.7	$	337.5	$	346.5	$	352.4	$	1,813.1
PBOP	58.1		57.9		57.3		56.8		56.2		264.7

Schedule of Allocation of Plan Assets

The following table presents, by asset category, the Pension and PBOP Plan assets recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:  

	Pension Plan
	Fair Value Measurements as of December 31,
(Millions of Dollars)	2019									2018
Asset Category:	Level 1		Level 2		Uncategorized		Total			Level 1		Level 2		Uncategorized		Total
Equity Securities (1)	$	592.6	$	—	$	1,349.9	$	1,942.5		$	443.4	$	—	$	1,377.8	$	1,821.2
Fixed Income (2)	99.4		303.0		1,222.8		1,625.2			85.5		160.8		1,265.5		1,511.8
Private Equity	16.9		—		971.4		988.3			6.1		—		834.0		840.1
Real Assets (3)	58.7		—		615.0		673.7			62.9		—		569.1		632.0
Total	$	767.6	$	303.0	$	4,159.1	$	5,229.7		$	597.9	$	160.8	$	4,046.4	$	4,805.1
Less:  401(h) PBOP Assets (4)							(261.1		)							(231.2		)
Total Pension Assets							$	4,968.6								$	4,573.9

	PBOP Plan
	Fair Value Measurements as of December 31,
(Millions of Dollars)	2019								2018
Asset Category:	Level 1		Level 2		Uncategorized		Total		Level 1		Level 2		Uncategorized		Total
Equity Securities (1)	$	158.0	$	—	$	187.0	$	345.0	$	91.9	$	—	$	210.5	$	302.4
Fixed Income (2)	15.8		39.6		148.1		203.5		22.0		40.3		123.0		185.3
Private Equity	—		—		26.5		26.5		—		—		32.7		32.7
Real Assets (3)	51.2		—		48.6		99.8		27.5		—		70.5		98.0
Total	$	225.0	$	39.6	$	410.2	$	674.8	$	141.4	$	40.3	$	436.7	$	618.4
Add:  401(h) PBOP Assets (4)							261.1								231.2
Total PBOP Assets							$	935.9							$	849.6

⁽¹⁾   United States, Global, Non-United States and Emerging Markets equity securities that are uncategorized include investments in commingled funds and hedge funds that are overlaid with equity index swaps and futures contracts.

⁽²⁾ Fixed Income investments that are uncategorized include investments in commingled funds, fixed income funds that invest in a variety of opportunistic and fixed income strategies, and hedge funds that are overlaid with fixed income futures.  

⁽³⁾   Real assets include real estate funds and hedge funds.

⁽⁴⁾   The assets of the Pension Plan include a 401(h) account that has been allocated to provide health and welfare postretirement benefits under the PBOP Plan.

These long-term rates of return are based on the assumed rates of return for the target asset allocations as follows:

	As of December 31,
	2019				2018
	Eversource Pension Plan and Tax-Exempt Assets Within PBOP Plan				Eversource Pension Plan and Tax-Exempt Assets Within PBOP Plan
	Target Asset Allocation		Assumed Rate of Return		Target Asset Allocation		Assumed Rate of Return
Equity Securities:
United States	15.0	%	8.5	%	15.0	%	8.5	%
Global	10.0	%	8.75	%	10.0	%	8.75	%
Non-United States	8.0	%	8.5	%	8.0	%	8.5	%
Emerging Markets	4.0	%	10.0	%	4.0	%	10.0	%
Debt Securities:
Fixed Income	13.0	%	4.0	%	13.0	%	4.0	%
Public High Yield Fixed Income	4.0	%	6.5	%	4.0	%	6.5	%
Private Debt	15.0	%	9.0	%	15.0	%	9.0	%
Private Equity	15.0	%	12.0	%	15.0	%	12.0	%
Real Assets	16.0	%	7.5	%	16.0	%	7.5	%

Schedule of Defined Contribution Plans

The total Eversource 401k Plan employer matching contributions, including the K-Vantage contributions, were as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	41.6	$	5.5	$	10.3	$	3.5
2018	38.4		5.0		9.7		3.3
2017	34.5		4.6		8.5		3.7

Schedule of Other Retirement Benefits

The liability and expense amounts are as follows:

Eversource (Millions of Dollars)	As of and For the Years Ended December 31,
	2019		2018		2017
Actuarially-Determined Liability	$	52.0	$	49.1	$	53.4
Other Retirement Benefits Expense	2.7		2.7		2.8

	As of and For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Actuarially-Determined   Liability	$	0.2	$	0.1	$	1.7	$	0.3	$	0.1	$	1.7	$	0.3	$	0.1	$	1.9
Other Retirement Benefits   Expense	1.0		0.9		0.4		1.1		1.1		0.4		1.0		1.0		0.5

Summary of Share Transactions

A summary of performance share transactions is as follows:

	Performance Shares (Units)		Weighted Average Grant-Date Fair Value
Outstanding as of December 31, 2018	499,564		$	56.08
Granted	165,022		$	68.33
Shares Issued	(162,959	)	$	55.69
Forfeited	(14,720	)	$	58.20
Outstanding as of December 31, 2019	486,907		$	60.30

A summary of RSU transactions is as follows:

	RSUs (Units)		Weighted Average Grant-Date Fair Value
Outstanding as of December 31, 2018	782,365		$	50.25
Granted	271,144		$	67.91
Shares Issued	(263,219	)	$	55.34
Forfeited	(16,127	)	$	63.31
Outstanding as of December 31, 2019	774,163		$	54.43

Schedule of Compensation Expense and Income Tax Benefit

The total compensation expense and associated future income tax benefits recognized by Eversource, CL&P, NSTAR Electric and PSNH for share-based compensation awards were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Compensation Expense	$	27.3	$	21.4	$	19.7
Future Income Tax Benefit	7.0		5.4		8.0

	For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Compensation Expense	$	9.8	$	9.7	$	3.3	$	7.8	$	7.7	$	2.9	$	7.0	$	7.0	$	3.2
Future Income Tax Benefit	2.5		2.5		0.8		2.0		1.9		0.7		2.9		2.8		1.3

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INVESTMENTS IN UNCONSOLIDATED AFFILIATES (Tables)

12 Months Ended

Dec. 31, 2019

Equity Method Investments and Joint Ventures [Abstract]

Summary of Investments

 Eversource's investments included the following:

			Investment Balance as of December 31,
(Millions of Dollars)	Ownership Interest		2019		2018
Offshore Wind Business - North East Offshore and Bay State Wind	50	%	$	649.3	$	234.3
Natural Gas Pipeline - Algonquin Gas Transmission, LLC	15	%	127.8		155.0
Renewable Energy Investment Fund	90	%	72.4		54.1
Other	various		22.1		20.9
Total Investments in Unconsolidated Affiliates			$	871.6	$	464.3

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ACQUISITION OF AQUARION AND GOODWILL - Narrative (Details) - USD ($)			12 Months Ended
	Oct. 01, 2019	Dec. 04, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Business Acquisition [Line Items]
Acquisition of Aquarion			$ 0	$ 0	$ 877,652,000
Operating Revenues					15,900,000
Pre-tax income					1,100,000
Impairment loss	$ 0
Aquarion Water Company
Business Acquisition [Line Items]
Consideration transferred		$ 1,675,000,000
Acquisition of Aquarion		880,000,000
Consideration transferred, liabilities incurred		795,000,000
Equity interest		745,000,000
Aquarion shareholder loan paid at closing		$ 135,000,000
Operating Revenues					$ 7,947,700,000

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ASSET RETIREMENT OBLIGATIONS - Narrative (Details) $ in Millions		12 Months Ended
	Jul. 15, 2016 kV	Dec. 31, 2019 USD ($) kV	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)
Schedule of Asset Retirement Obligation [Line Items]
Asset retirement obligations		$ 489.5	$ 466.2	$ 419.1
Amount of capacity required for installation of distribution cable (in kV) | kV	115	115
Eversource and NSTAR Electric | Other Current Liabilities
Schedule of Asset Retirement Obligation [Line Items]
Asset retirement obligations		$ 1.0
CYAPC and YAEC
Schedule of Asset Retirement Obligation [Line Items]
Asset retirement obligations		$ 337.7	$ 339.9

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PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION - Schedule of Average Remaining Useful Lives of Depreciable Assets (Details)	12 Months Ended
	Dec. 31, 2019
Property, Plant and Equipment [Line Items]
Distribution - Electric	34 years 3 months 18 days
Distribution - Natural Gas	43 years 2 months 12 days
Transmission - Electric	40 years 4 months 24 days
Distribution - Water	33 years 6 months
Solar	24 years 2 months 12 days
Other	11 years 2 months 12 days
Computer Software, Hardware and Equipment | Minimum
Property, Plant and Equipment [Line Items]
Estimated useful life of property, plant and equipment	5 years
Computer Software, Hardware and Equipment | Maximum
Property, Plant and Equipment [Line Items]
Estimated useful life of property, plant and equipment	15 years
Buildings
Property, Plant and Equipment [Line Items]
Estimated useful life of property, plant and equipment	40 years
CL&P
Property, Plant and Equipment [Line Items]
Distribution - Electric	35 years 3 months 18 days
Transmission - Electric	36 years 9 months 18 days
NSTAR Electric
Property, Plant and Equipment [Line Items]
Distribution - Electric	33 years 8 months 12 days
Transmission - Electric	44 years 10 months 24 days
Solar	24 years 2 months 12 days
PSNH
Property, Plant and Equipment [Line Items]
Distribution - Electric	33 years 2 months 12 days
Transmission - Electric	42 years 1 month 6 days

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REGULATORY ACCOUNTING - Components of Regulatory Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 4,019,200	$ 3,979,700
Less: Current Portion	361,152	370,230
Total Long-Term Regulatory Liabilities	3,658,042	3,609,475
EDIT due to Tax Cuts and Jobs Act
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	2,844,600	2,883,000
Cost of Removal
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	559,800	521,000
Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	84,500	91,200
Regulatory Tracker Mechanisms
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	325,100	309,000
AFUDC - Transmission
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	73,200	70,700
Revenue Subject to Refund due to Tax Cuts and Jobs Act
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	14,600	24,600
Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	117,400	80,200
CL&P
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	1,247,800	1,231,800
Less: Current Portion	82,763	109,614
Total Long-Term Regulatory Liabilities	1,164,991	1,122,157
CL&P | EDIT due to Tax Cuts and Jobs Act
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	1,022,800	1,031,000
CL&P | Cost of Removal
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	64,600	39,900
CL&P | Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	0	0
CL&P | Regulatory Tracker Mechanisms
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	94,800	89,500
CL&P | AFUDC - Transmission
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	46,000	47,400
CL&P | Revenue Subject to Refund due to Tax Cuts and Jobs Act
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	0	0
CL&P | Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	19,600	24,000
NSTAR Electric
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	1,725,800	1,703,900
Less: Current Portion	209,180	190,620
Total Long-Term Regulatory Liabilities	1,516,585	1,513,279
NSTAR Electric | EDIT due to Tax Cuts and Jobs Act
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	1,071,200	1,103,700
NSTAR Electric | Cost of Removal
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	330,600	307,100
NSTAR Electric | Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	72,200	76,900
NSTAR Electric | Regulatory Tracker Mechanisms
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	165,600	163,700
NSTAR Electric | AFUDC - Transmission
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	27,200	23,300
NSTAR Electric | Revenue Subject to Refund due to Tax Cuts and Jobs Act
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	0	0
NSTAR Electric | Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	59,000	29,200
PSNH
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	479,200	483,600
Less: Current Portion	65,766	55,526
Total Long-Term Regulatory Liabilities	413,381	428,069
PSNH | EDIT due to Tax Cuts and Jobs Act
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	392,800	396,400
PSNH | Cost of Removal
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	16,300	22,100
PSNH | Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	0	0
PSNH | Regulatory Tracker Mechanisms
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	57,000	48,300
PSNH | AFUDC - Transmission
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	0	0
PSNH | Revenue Subject to Refund due to Tax Cuts and Jobs Act
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	6,000	12,600
PSNH | Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 7,100	$ 4,200

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SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS AND RESERVES (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
CL&P
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Period of accounts receivable recoverable under financial or medical duress		180 days
Yankee Gas Services Company
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Period of accounts receivable recoverable under financial or medical duress		90 days
Allowance for Doubtful Accounts
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period		$ 212,723	$ 195,708	$ 200,630
Additions, Charged to Costs and Expense		63,446	61,337	44,665
Additions, Charged to Other Accounts	[1]	57,223	48,671	47,630
Deductions	[2]	108,571	92,993	97,217
Balance at end of period		224,821	212,723	195,708
Allowance for Doubtful Accounts | CL&P
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period		88,034	78,872	86,391
Additions, Charged to Costs and Expense		15,947	15,831	5,312
Additions, Charged to Other Accounts	[1]	38,935	29,524	25,533
Deductions	[2]	45,568	36,193	38,364
Balance at end of period		97,348	88,034	78,872
Allowance for Doubtful Accounts | NSTAR Electric
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period		74,516	69,666	70,284
Additions, Charged to Costs and Expense		25,079	22,279	21,252
Additions, Charged to Other Accounts	[1]	12,556	14,971	14,273
Deductions	[2]	36,745	32,400	36,143
Balance at end of period		75,406	74,516	69,666
Allowance for Doubtful Accounts | PSNH
SEC Schedule, 12-09, Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period		11,065	10,481	9,941
Additions, Charged to Costs and Expense		6,726	6,383	6,917
Additions, Charged to Other Accounts	[1]	872	953	464
Deductions	[2]	8,166	6,752	6,841
Balance at end of period		$ 10,497	$ 11,065	$ 10,481

[1] Amounts relate to uncollectible accounts receivables reserved for that are not charged to bad debt expense.  The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively.  The DPU allows NSTAR Electric and NSTAR Gas to recover in rates, amounts associated with certain uncollectible hardship accounts receivable. 

[2] Amounts written off, net of recoveries.

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MARKETABLE SECURITIES - Contractual Maturity (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Amortized Cost
Less than one year	$ 59.2
One to five years	40.5
Six to ten years	33.6
Greater than ten years	95.1
Amortized Cost	228.4	$ 190.0
Fair Value
Less than one year	59.3
One to five years	41.4
Six to ten years	34.8
Greater than ten years	98.6
Total Debt Securities	$ 234.1	$ 186.4

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DERIVATIVE INSTRUMENTS - Variations Using Significant unobservable Inputs (Details) - Level 3 - CL&P - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ (356.5)	$ (362.3)
Net Realized/Unrealized Losses Included in Regulatory Assets	(15.0)	(32.0)
Settlements	42.3	37.8
Ending balance	$ (329.2)	$ (356.5)

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LONG-TERM DEBT - Narrative (Details) - USD ($)	1 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Jan. 27, 2020	Dec. 11, 2019	Aug. 14, 2019	Apr. 26, 2019	Feb. 27, 2019
Debt Instrument [Line Items]
Long-Term Debt	$ 13,770,828,000	$ 12,248,743,000
Payment to DOE	29,000,000	145,000,000
Interest included in payment to settle spent nuclear fuel obligation	8,600,000	29,000,000.0
NSTAR Electric
Debt Instrument [Line Items]
Amount of long-term debt approved for issuance							$ 800,000,000
Long-Term Debt	3,247,086,000	2,944,846,000
PSNH
Debt Instrument [Line Items]
Amount of long-term debt approved for issuance						$ 300,000,000
Long-Term Debt	951,620,000	655,173,000
CL&P
Debt Instrument [Line Items]
Amount of long-term debt approved for issuance					$ 675,000,000
Long-Term Debt	3,518,136,000	3,004,016,000
Aquarion
Debt Instrument [Line Items]
Amount of long-term debt approved for issuance				$ 45,000,000
Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)
Debt Instrument [Line Items]
Long-Term Debt	$ 11,600,000	$ 39,500,000
Subsequent Event | NSTAR Gas
Debt Instrument [Line Items]
Amount of long-term debt approved for issuance			$ 270,000,000

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ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) - Schedule of Amounts Reclassified From AOCI By Component (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Tax Effect									$ (273,499)	$ (288,972)	$ (578,892)
Net Income Attributable to Common Shareholders	$ 250,000	$ 318,900	$ 31,500	$ 308,700	$ 231,300	$ 289,400	$ 242,800	$ 269,500	909,053	1,033,000	987,996
Defined Benefit Plan Costs:
Total Amounts Reclassified from AOCI, Net of Tax									7,000	6,600	6,500
Accumulated Net Gain (Loss) from Cash Flow Hedges Including Portion Attributable to Noncontrolling Interest | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Tax Effect									1,100	1,000	1,300
Qualified Cash Flow Hedging Instruments, Net of Tax | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income Attributable to Common Shareholders									(1,400)	(1,800)	(2,000)
Amortization of Actuarial Losses
Defined Benefit Plan Costs:
Reclassifications from AOCI									(5,700)	(6,000)	(6,200)
Amortization of Prior Service Cost
Defined Benefit Plan Costs:
Reclassifications from AOCI									(1,800)	(400)	(1,100)
Defined Benefit Plans
Defined Benefit Plan Costs:
Reclassifications from AOCI									(7,500)	(6,400)	(7,300)
Tax Effect									1,900	1,600	2,800
Total Amounts Reclassified from AOCI, Net of Tax									(5,600)	(4,800)	(4,500)
Interest Expense | Accumulated Net Gain (Loss) from Cash Flow Hedges Including Portion Attributable to Noncontrolling Interest | Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Qualified Cash Flow Hedging Instruments									$ (2,500)	$ (2,800)	$ (3,300)

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ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) (Tables)

12 Months Ended

Dec. 31, 2019

Equity [Abstract]

Changes in Accumulated Other Comprehensive Income/(Loss) by Component, Net of Tax

The changes in accumulated other comprehensive income/(loss) by component, net of tax, are as follows:

	For the Year Ended December 31, 2019												For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Qualified Cash Flow Hedging Instruments			Unrealized Gains/(Losses) on Marketable Securities			Defined Benefit Plans			Total			Qualified Cash Flow Hedging Instruments			Unrealized Losses on Marketable Securities			Defined Benefit Plans			Total
Balance as of January 1st	$	(4.4	)	$	(0.5	)	$	(55.1	)	$	(60.0	)	$	(6.2	)	$	—		$	(60.2	)	$	(66.4	)
OCI Before Reclassifications	—			1.2			(13.3		)	(12.1		)	—			(0.5		)	0.3			(0.2		)
Amounts Reclassified from AOCI	1.4			—			5.6			7.0			1.8			—			4.8			6.6
Net OCI	1.4			1.2			(7.7		)	(5.1		)	1.8			(0.5		)	5.1			6.4
Balance as of December 31st	$	(3.0	)	$	0.7		$	(62.8	)	$	(65.1	)	$	(4.4	)	$	(0.5	)	$	(55.1	)	$	(60.0	)

Schedule of Amounts Reclassified From AOCI By Component

The following table sets forth the amounts reclassified from AOCI by component and the impacted line item on the statements of income:

	Amounts Reclassified from AOCI
Eversource (Millions of Dollars)	For the Years Ended December 31,									Statements of Income Line Item Impacted
	2019			2018			2017
Qualified Cash Flow Hedging Instruments	$	(2.5	)	$	(2.8	)	$	(3.3	)	Interest Expense
Tax Effect	1.1			1.0			1.3			Income Tax Expense
Qualified Cash Flow Hedging Instruments, Net of Tax	$	(1.4	)	$	(1.8	)	$	(2.0	)
Defined Benefit Plan Costs:
Amortization of Actuarial Losses	$	(5.7	)	$	(6.0	)	$	(6.2	)	Other Income, Net (1)
Amortization of Prior Service Cost	(1.8		)	(0.4		)	(1.1		)	Other Income, Net (1)
Total Defined Benefit Plan Costs	(7.5		)	(6.4		)	(7.3		)
Tax Effect	1.9			1.6			2.8			Income Tax Expense
Defined Benefit Plan Costs, Net of Tax	$	(5.6	)	$	(4.8	)	$	(4.5	)
Total Amounts Reclassified from AOCI, Net of Tax	$	(7.0	)	$	(6.6	)	$	(6.5	)

⁽¹⁾ 

These amounts are included in the computation of net periodic Pension, SERP and PBOP costs.  See Note 1M, "Summary of Significant Accounting Policies – Other Income, Net" and Note 11A, "Employee Benefits – Pension Benefits and Postretirement Benefits Other Than Pension," for further information.

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REVENUES (Tables)

12 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue

The following table presents operating revenues disaggregated by revenue source:

	For the Year Ended December 31, 2019
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution			Electric Transmission		Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	3,723.7	$	555.1		$	—	$	132.3		$	—	$	—		$	4,411.1
Commercial	2,584.8		347.6			—		63.9			—		(4.3		)	2,992.0
Industrial	331.8		96.9			—		4.5			—		(11.6		)	421.6
Total Retail Tariff Sales Revenues	6,640.3		999.6			—		200.7			—		(15.9		)	7,824.7
Wholesale Transmission Revenues	—		—			1,293.3		—			61.3		(1,085.2		)	269.4
Wholesale Market Sales Revenues	215.7		55.4			—		4.1			—		—			275.2
Other Revenues from Contracts with Customers	54.8		2.8			13.2		7.0			967.2		(969.0		)	76.0
Reserve for Revenues Subject to Refund	1.3		6.2			—		(2.8		)	—		—			4.7
Total Revenues from Contracts with Customers	6,912.1		1,064.0			1,306.5		209.0			1,028.5		(2,070.1		)	8,450.0
Alternative Revenue Programs	45.9		(4.9		)	81.8		4.6			—		(74.2		)	53.2
Other Revenues	18.5		3.1			0.7		1.0			—		—			23.3
Total Operating Revenues	$	6,976.5	$	1,062.2		$	1,389.0	$	214.6		$	1,028.5	$	(2,144.3	)	$	8,526.5

	For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	3,766.6		$	542.5		$	—		$	130.7		$	—	$	—		$	4,439.8
Commercial	2,634.7			334.8			—			63.3			—		(4.5		)	3,028.3
Industrial	351.9			96.0			—			4.4			—		(10.0		)	442.3
Total Retail Tariff Sales Revenues	6,753.2			973.3			—			198.4			—		(14.5		)	7,910.4
Wholesale Transmission Revenues	—			—			1,308.9			—			47.3		(1,092.2		)	264.0
Wholesale Market Sales Revenues	179.5			57.5			—			4.1			—		—			241.1
Other Revenues from Contracts with Customers	65.9			(2.2		)	12.6			7.2			889.0		(891.0		)	81.5
Reserve for Revenues Subject to Refund	(12.3		)	(8.3		)	—			(3.7		)	—		—			(24.3		)
Total Revenues from Contracts with Customers	6,986.3			1,020.3			1,321.5			206.0			936.3		(1,997.7		)	8,472.7
Alternative Revenue Programs	(47.0		)	(1.2		)	(35.2		)	5.4			—		31.9			(46.1		)
Other Revenues	17.9			3.1			—			0.6			—		—			21.6
Total Operating Revenues	$	6,957.2		$	1,022.2		$	1,286.3		$	212.0		$	936.3	$	(1,965.8	)	$	8,448.2

	For the Years Ended December 31,
	2019									2018
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	1,837.1		$	1,322.1		$	564.5		$	1,828.2		$	1,380.9		$	557.5
Commercial	922.9			1,349.4			314.6			928.1			1,391.5			316.9
Industrial	138.3			115.8			77.7			147.7			124.9			79.3
Total Retail Tariff Sales Revenues	2,898.3			2,787.3			956.8			2,904.0			2,897.3			953.7
Wholesale Transmission Revenues	587.1			517.3			188.9			620.6			488.8			199.5
Wholesale Market Sales Revenues	105.1			73.1			37.5			48.3			76.1			56.6
Other Revenues from Contracts with Customers	36.4			18.7			15.6			35.0			28.9			15.5
Reserve for Revenues Subject to Refund	—			—			1.3			—			—			(12.3		)
Total Revenues from Contracts with Customers	3,626.9			3,396.4			1,200.1			3,607.9			3,491.1			1,213.0
Alternative Revenue Programs	77.5			41.6			8.6			(65.9		)	0.9			(17.3		)
Other Revenues	10.3			7.0			1.9			8.5			8.3			1.1
Eliminations	(482.1		)	(400.4		)	(144.7		)	(454.3		)	(387.4		)	(149.2		)
Total Operating Revenues	$	3,232.6		$	3,044.6		$	1,065.9		$	3,096.2		$	3,112.9		$	1,047.6

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COMMON SHARES - Narrative (Details) - USD ($) $ / shares in Units, $ in Thousands			12 Months Ended
	Dec. 30, 2019	Jun. 04, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Equity [Abstract]
Equity offering (in shares)		17,940,000
Common shares issued directly by the Company (in shares)		5,980,000	11,980,000
Common shares issuable pursuant to forward sale agreement (in shares)	6,000,000	11,960,000
Net proceeds from common shares issued directly by the Company	$ 425,400	$ 426,900	$ 852,254	$ 0	$ 0
Forward sale price (in dollars per share)	$ 71.48
Amount that would have been required to be paid if net settled			$ 84,400
Shares that would have been required to be delivered if net settled (in shares)			992,189
Treasury stock (in shares)			15,977,757	16,992,594
Common stock outstanding (in shares)			329,880,645	316,885,808

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

Provision for Uncollectible Accounts

The provision balances were as follows:

	Total Provision for Uncollectible Accounts				Provision for Uncollectible Hardship Accounts
	As of December 31,				As of December 31,
(Millions of Dollars)	2019		2018		2019		2018
Eversource	$	224.8	$	212.7	$	143.3	$	131.5
CL&P	97.3		88.0		80.1		71.9
NSTAR Electric	75.4		74.5		43.9		42.5
PSNH	10.5		11.1		—		—

Uncollectible expense associated with customers' accounts receivable included in Operations and Maintenance expense on the statements of income was as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource	$	63.4	$	61.3	$	44.5
CL&P	15.9		15.8		5.3
NSTAR Electric	25.1		22.3		21.3
PSNH	6.7		6.4		6.7

Schedule of Utility Inventory

The carrying amounts of fuel, materials and supplies, and RECs, which are included in Current Assets on the balance sheets, were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Fuel	$	26.7	$	—	$	—	$	—	$	33.1	$	—	$	—	$	—
Materials and Supplies	132.9		50.7		54.7		18.5		126.1		44.5		48.6		24.3
RECs	75.9		—		69.4		6.5		78.8		—		65.6		13.2
Total	$	235.5	$	50.7	$	124.1	$	25.0	$	238.0	$	44.5	$	114.2	$	37.5

Costs related to fuel and natural gas

Costs related to fuel and natural gas included in Purchased Power, Fuel and Transmission on the statements of income were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource - Natural Gas and Fuel	$	462.1	$	442.6	$	432.5
PSNH - Fuel	—		7.9		43.4

Weighted-average AFUDC rates

AFUDC costs and the weighted-average AFUDC rates were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars, except percentages)	2019			2018			2017
Borrowed Funds	$	25.6		$	19.7		$	12.5
Equity Funds	45.0			44.0			34.4
Total AFUDC	$	70.6		$	63.7		$	46.9
Average AFUDC Rate	5.4		%	4.9		%	5.1		%

	For the Years Ended December 31,
	2019									2018									2017
(Millions of Dollars, except percentages)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Borrowed Funds	$	7.1		$	10.4		$	2.8		$	6.3		$	7.8		$	1.3		$	5.1		$	4.8		$	0.7
Equity Funds	13.2			19.8			3.4			12.2			15.6			—			12.1			10.2			—
Total AFUDC	$	20.3		$	30.2		$	6.2		$	18.5		$	23.4		$	1.3		$	17.2		$	15.0		$	0.7
Average AFUDC Rate	6.3		%	5.7		%	4.6		%	5.8		%	5.0		%	0.7		%	6.2		%	5.0		%	0.7		%

Components of Other Income, Net

The components of Other Income, Net on the statements of income were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018			2017
Pension, SERP and PBOP Non-Service Income Components	$	31.3	$	60.8		$	29.9
AFUDC Equity	45.0		44.0			34.4
Equity in Earnings of Unconsolidated Affiliates (1)	42.2		3.8			27.4
Investment Income/(Loss)	0.8		(4.0		)	7.5
Interest Income (2)	12.8		18.1			8.3
Gains on Sales of Property	0.3		5.1			—
Other	0.4		0.6			0.4
Total Other Income, Net	$	132.8	$	128.4		$	107.9

	For the Years Ended December 31,
	2019								2018									2017
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH		CL&P			NSTAR Electric			PSNH			CL&P		NSTAR Electric		PSNH
Pension, SERP and PBOP Non-Service   Income Components	$	0.5		$	23.5		$	4.9	$	9.5		$	36.0		$	9.9		$	1.8	$	19.2	$	5.9
AFUDC Equity	13.2			19.8			3.4		12.2			15.6			—			12.1		10.2		—
Equity in Earnings of Unconsolidated Affiliates	0.1			0.7			—		0.1			0.7			—			—		0.3		—
Investment Income/(Loss)	2.3			(0.4		)	0.3		(3.0		)	(0.5		)	(0.8		)	4.5		2.6		1.6
Interest Income (2)	1.5			0.7			10.5		3.7			0.8			14.1			4.6		1.8		2.2
Gains on Sales of Property	—			0.1			—		—			0.5			4.4			—		—		—
Other	(0.1		)	0.2			0.1		0.2			—			0.1			—		—		0.1
Total Other Income, Net	$	17.5		$	44.6		$	19.2	$	22.7		$	53.1		$	27.7		$	23.0	$	34.1	$	9.8

⁽¹⁾  Equity in earnings of unconsolidated affiliates includes an other-than-temporary impairment of $32.9 million of the Access Northeast project investment for the year ended December 31, 2018. See Note 6, "Investments in Unconsolidated Affiliates," for further information. Equity in earnings includes $20.4 million, $17.6 million and $9.7 million of pre-tax unrealized gains for the years ended December 31, 2019, 2018 and 2017, respectively, associated with an equity method investment in a renewable energy fund.

⁽²⁾ For the years ended December 31, 2019 and 2018, PSNH recognized $6.3 million and $8.7 million, respectively, of interest income for the equity return component of carrying charges on storm costs approved in 2019 and 2018. See Note 2, "Regulatory Accounting," for further information.

Other Taxes

These gross receipts taxes are recorded separately with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the statements of income as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource	$	163.1	$	161.9	$	157.4
CL&P	141.1		141.4		137.5

Supplemental Cash Flow Information

Eversource (Millions of Dollars)	As of and For the Years Ended December 31,
	2019		2018		2017
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	$	532.4	$	503.2	$	419.1
Income Taxes	56.0		158.8		30.8
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of) (1)	379.4		389.3		379.5

	As of and For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	$	144.6	$	121.9	$	56.9	$	149.7	$	122.1	$	40.5	$	144.6	$	124.6	$	45.9
Income Taxes	80.6		77.9		3.4		66.1		120.0		27.3		68.8		95.5		26.1
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of) (1)	111.3		116.4		49.9		106.1		116.5		35.1		132.5		116.5		44.4

⁽¹⁾ See Note 1B, "Summary of Significant Accounting Policies - Basis of Presentation," for information regarding the correction of non-cash capital additions at Eversource and PSNH reported as of December 31, 2018.

Cash and cash equivalents as reported on the balance sheet

The following table reconciles cash as reported on the balance sheets to the cash and restricted cash balance as reported on the statements of cash flows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Cash as reported on the Balance Sheets	$	15.4	$	—	$	0.1	$	0.4	$	108.1	$	87.7	$	1.6	$	1.4
Restricted cash included in:
Special Deposits	52.5		4.6		6.2		32.5		72.1		3.5		13.0		47.5
Marketable Securities	46.0		0.4		—		0.6		25.9		0.4		0.1		0.6
Other Long-Term Assets	3.2		—		—		3.2		3.2		—		—		3.2
Cash and Restricted Cash reported on the     Statements of Cash Flows	$	117.1	$	5.0	$	6.3	$	36.7	$	209.3	$	91.6	$	14.7	$	52.7

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CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating Revenues	$ 8,526,470	$ 8,448,201	$ 7,751,952
Operating Expenses:
Purchased Power, Fuel and Transmission	3,040,160	3,138,969	2,535,271
Operations and Maintenance	1,363,113	1,335,213	1,307,052
Depreciation	885,278	819,930	773,802
Amortization of Regulatory Assets/(Liabilities), Net	195,380	252,026	89,986
Energy Efficiency Programs	501,369	472,380	480,835
Taxes Other Than Income Taxes	711,035	729,753	676,757
Impairment of Northern Pass Transmission	239,644	0	0
Total Operating Expenses	6,935,979	6,748,271	5,863,703
Operating Income	1,590,491	1,699,930	1,888,249
Interest Expense	533,197	498,805	421,755
Other Income, Net	132,777	128,366	107,913
Income Before Income Tax Expense	1,190,071	1,329,491	1,574,407
Income Tax Expense	273,499	288,972	578,892
Net Income	916,572	1,040,519	995,515
Net Income Attributable to Noncontrolling Interests	7,519	7,519	7,519
Net Income Attributable to Common Shareholders	$ 909,053	$ 1,033,000	$ 987,996
Basic Earnings Per Common Share (in dollars per share)	$ 2.83	$ 3.25	$ 3.11
Diluted Earnings Per Common Share (in dollars per share)	$ 2.81	$ 3.25	$ 3.11
Weighted Average Common Shares Outstanding:
Basic (in shares)	321,416,086	317,370,369	317,411,097
Diluted (in shares)	322,941,636	317,993,934	318,031,580
The Connecticut Light and Power Company
Operating Revenues	$ 3,232,551	$ 3,096,174	$ 2,887,359
Operating Expenses:
Purchased Power, Fuel and Transmission	1,188,202	1,095,187	930,780
Operations and Maintenance	549,167	506,448	502,107
Depreciation	301,188	278,557	249,352
Amortization of Regulatory Assets/(Liabilities), Net	51,621	129,021	83,166
Energy Efficiency Programs	118,235	93,977	114,713
Taxes Other Than Income Taxes	342,489	357,147	323,887
Total Operating Expenses	2,550,902	2,460,337	2,204,005
Operating Income	681,649	635,837	683,354
Interest Expense	151,357	151,727	142,973
Other Income, Net	17,531	22,663	22,991
Income Before Income Tax Expense	547,823	506,773	563,372
Income Tax Expense	136,971	129,056	186,646
Net Income	410,852	377,717	376,726
NSTAR Electric Company
Operating Revenues	3,044,642	3,112,926	2,980,629
Operating Expenses:
Purchased Power, Fuel and Transmission	1,064,289	1,257,073	1,025,414
Operations and Maintenance	468,436	462,100	482,924
Depreciation	296,500	276,372	274,008
Amortization of Regulatory Assets/(Liabilities), Net	103,735	46,654	33,831
Energy Efficiency Programs	289,206	292,288	294,053
Taxes Other Than Income Taxes	195,586	194,316	181,959
Total Operating Expenses	2,417,752	2,528,803	2,292,189
Operating Income	626,890	584,123	688,440
Interest Expense	114,198	105,193	105,729
Other Income, Net	44,577	53,066	34,100
Income Before Income Tax Expense	557,269	531,996	616,811
Income Tax Expense	125,313	148,906	242,085
Net Income	431,956	383,090	374,726
Public Service Company of New Hampshire
Operating Revenues	1,065,936	1,047,619	981,624
Operating Expenses:
Purchased Power, Fuel and Transmission	398,449	370,246	237,478
Operations and Maintenance	210,995	210,541	263,110
Depreciation	93,737	92,055	128,192
Amortization of Regulatory Assets/(Liabilities), Net	57,732	80,978	(16,577)
Energy Efficiency Programs	25,982	20,105	13,788
Taxes Other Than Income Taxes	62,574	77,280	89,760
Total Operating Expenses	849,469	851,205	715,751
Operating Income	216,467	196,414	265,873
Interest Expense	60,666	60,634	51,007
Other Income, Net	19,222	27,672	9,805
Income Before Income Tax Expense	175,023	163,452	224,671
Income Tax Expense	40,975	47,576	88,675
Net Income	$ 134,048	$ 115,876	$ 135,996

XML

COMMITMENTS AND CONTINGENCIES - Schedule of Guarantees and Indemnifications (Details) - USD ($) $ in Millions	Dec. 31, 2019	Oct. 25, 2019
Various - Surety Bonds
Guarantor Obligations [Line Items]
Maximum Exposure	$ 29.2
Rocky River Realty Company and Eversource Service - Lease Payments for Real Estate
Guarantor Obligations [Line Items]
Maximum Exposure	6.5
Bay State Wind LLC - Real Estate Purchase
Guarantor Obligations [Line Items]
Maximum Exposure	2.5
Sunrise Wind LLC - Offshore Wind
Guarantor Obligations [Line Items]
Maximum Exposure	$ 2.2
Sunrise Wind, LLC
Guarantor Obligations [Line Items]
Maximum Exposure		$ 15.4
Ownership interest		50.00%

XML

COMMITMENTS AND CONTINGENCIES - Long-Term Contractual Arrangement Narrative (Details) MWh in Millions, $ in Millions				12 Months Ended
	Nov. 22, 2019 megawatt	Mar. 15, 2019 megawatt	Dec. 28, 2018 MWh	Dec. 31, 2019 USD ($) contract project MW	Dec. 31, 2008 contract MW	Dec. 31, 2018 MW
Long-term Purchase Commitment [Line Items]
Estimated cost of energy purchase contracts				$ 9,451.5
Number of capacity contracts for differences between CL&P and UI | contract				3
Amount of capacity contracts for differences between CL&P and UI (in MW) | MW				676		787
Number of generation projects between CL&P and United Illuminated Company | project				2
Number of demand response projects between CL&P and United Illuminated Company | project				1
Percentage of costs and benefits borne by United Illuminated Company				20.00%
Peaker Contracts For Differences
Long-term Purchase Commitment [Line Items]
Estimated cost of energy purchase contracts				$ 127.7
Percentage of costs and benefits borne by United Illuminated Company					20.00%
Period of payment to generation facility owner					30 years
CL&P
Long-term Purchase Commitment [Line Items]
Estimated cost of energy purchase contracts				5,804.8
CL&P | Peaker Contracts For Differences
Long-term Purchase Commitment [Line Items]
Estimated cost of energy purchase contracts				$ 127.7
Number of capacity contracts | contract					3
Amount of peaking capacity contracts (in MW) | MW					500
Percentage of costs and benefits borne					80.00%
CL&P, NSTAR Electric and PSNH | Transmission Support Commitments
Long-term Purchase Commitment [Line Items]
Period of payment of annual operation and maintenance expense				30 years
Millstone Nuclear Power Station and Seabrook Nuclear Power Plant
Long-term Purchase Commitment [Line Items]
Estimated cost of energy purchase contracts				$ 4,100.0
Milestone Nuclear Power Station
Long-term Purchase Commitment [Line Items]
Annual purchase requirement (in MWh) | MWh			9
Percent of the facility's output required to be purchased		50.00%
Nameplate capacity (in MW) | megawatt		2,112
Milestone Nuclear Power Station | CL&P
Long-term Purchase Commitment [Line Items]
Contract term		10 years	10 years
Percent of the facility's output required to be purchased		40.00%
Milestone Nuclear Power Station | UI
Long-term Purchase Commitment [Line Items]
Contract term		10 years	10 years
Seabrook Nuclear Power Plant
Long-term Purchase Commitment [Line Items]
Percent of the facility's output required to be purchased	18.00%
Nameplate capacity (in MW) | megawatt	1,250
Seabrook Nuclear Power Plant | CL&P
Long-term Purchase Commitment [Line Items]
Contract term	8 years		8 years
Percent of the facility's output required to be purchased	15.00%
Seabrook Nuclear Power Plant | UI
Long-term Purchase Commitment [Line Items]
Contract term	8 years		8 years

XML

QUARTERLY FINANCIAL DATA (UNAUDITED)

12 Months Ended

Dec. 31, 2019

Quarterly Financial Data [Abstract]

QUARTERLY FINANCIAL DATA (UNAUDITED)

QUARTERLY FINANCIAL DATA (UNAUDITED)

	Quarter Ended
Eversource (Millions of Dollars, except   per share information)	2019								2018
	March 31,		June 30, (2)		September 30,		December 31,		March 31,		June 30,		September 30,		December 31,
Operating Revenues	$	2,415.8	$	1,884.5	$	2,175.8	$	2,050.4	$	2,288.0	$	1,853.9	$	2,271.4	$	2,034.9
Operating Income	494.7		151.0		509.2		435.6		442.5		391.4		466.0		400.0
Net Income	310.6		33.3		320.8		251.9		271.4		244.6		291.3		233.2
Net Income Attributable   to Common Shareholders	308.7		31.5		318.9		250.0		269.5		242.8		289.4		231.3
Basic EPS (1)	$	0.97	$	0.10	$	0.98	$	0.77	$	0.85	$	0.76	$	0.91	$	0.73
Diluted EPS (1)	$	0.97	$	0.10	$	0.98	$	0.76	$	0.85	$	0.76	$	0.91	$	0.73

⁽¹⁾    The summation of quarterly EPS data may not equal annual data due to rounding.

⁽²⁾  In the second quarter of 2019, Eversource recorded an impairment charge related to NPT of $239.6 million within Operating Income on the statement of income. For further information, see Note 1D, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements.

	Quarter Ended
	2019								2018
(Millions of Dollars)	March 31,		June 30,		September 30,		December 31,		March 31,		June 30,		September 30,		December 31,
CL&P
Operating Revenues	$	849.2	$	740.8	$	853.9	$	788.7	$	785.0	$	694.9	$	865.0	$	751.3
Operating Income	171.8		166.8		190.3		152.7		157.2		163.1		172.7		142.8
Net Income	110.5		104.8		111.7		83.9		98.6		99.7		100.3		79.1
NSTAR Electric
Operating Revenues	$	797.6	$	681.9	$	878.7	$	686.4	$	770.1	$	690.7	$	939.5	$	712.6
Operating Income	137.8		134.2		219.4		135.5		119.0		133.6		205.5		126.0
Net Income	94.0		89.7		154.9		93.4		77.1		87.9		140.6		77.5
PSNH
Operating Revenues	$	276.4	$	240.9	$	280.4	$	268.2	$	267.4	$	235.1	$	290.2	$	254.9
Operating Income	49.7		46.3		64.5		56.0		55.8		46.9		56.5		37.2
Net Income	32.8		26.9		40.9		33.4		35.1		25.8		40.7		14.3

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CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating Activities:
Net Income	$ 916,572	$ 1,040,519	$ 995,515
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	885,278	819,930	773,802
Deferred Income Taxes	209,812	174,812	491,630
Uncollectible Expense	63,446	61,337	44,453
Pension, SERP and PBOP Expense, Net	22,000	5,498	22,454
Pension and PBOP Contributions	(121,782)	(194,947)	(242,800)
Regulatory (Under)/Over Recoveries, Net	(124,870)	34,920	(47,935)
Amortization	195,380	252,026	89,986
Payments Related to CYAPC's DOE Pre-1983 Spent Nuclear Fuel Obligation	(29,000)	(145,000)	0
Proceeds from DOE Spent Nuclear Fuel Litigation	68,840	0	0
Impairment of Northern Pass Transmission	239,644	0	0
Other	(196,087)	(111,225)	(204,421)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(98,716)	(141,433)	(117,155)
Fuel, Materials, Supplies and REC Inventory	(8,074)	(831)	(9,223)
Taxes Receivable/Accrued, Net	(16,129)	(67,770)	52,284
Accounts Payable	14,866	24,481	56,067
Other Current Assets and Liabilities, Net	(11,603)	78,226	91,545
Net Cash Flows Provided by Operating Activities	2,009,577	1,830,543	1,996,202
Investing Activities:
Investments in Property, Plant and Equipment	(2,911,489)	(2,569,936)	(2,348,105)
Proceeds from Sales of Marketable Securities	566,592	900,749	832,903
Proceeds from Sales of Marketable Securities Used to Pay Pre-1983 Spent Nuclear Fuel Obligation	0	145,000	0
Purchases of Marketable Securities	(537,258)	(908,387)	(810,507)
Acquisition of Aquarion	0	0	(877,652)
Investments in Unconsolidated Affiliates, Net	(416,337)	(205,150)	(32,634)
Proceeds from the Sale of PSNH Generation Assets	0	193,924	0
Other Investing Activities	24,204	6,754	5,479
Net Cash Flows Used in Investing Activities	(3,274,288)	(2,437,046)	(3,230,516)
Financing Activities:
Issuance of Common Shares, Net of Issuance Costs	852,254	0	0
Cash Dividends on Common Shares	(663,239)	(640,110)	(602,083)
Cash Dividends on Preferred Stock	(7,519)	(7,519)	(7,519)
Increase/(Decrease) in Notes Payable	325,370	(379,310)	72,810
(Repayments)/Issuance of Rate Reduction Bonds	(52,332)	635,663	0
Issuance of Long-Term Debt	1,520,000	2,200,000	2,500,000
Retirement of Long-Term Debt	(801,078)	(1,050,330)	(745,000)
Other Financing Activities	(1,006)	(28,457)	(4,754)
Net Cash Flows Provided by/(Used in) Financing Activities	1,172,450	729,937	1,213,454
Net (Decrease)/Increase in Cash and Restricted Cash	(92,261)	123,434	(20,860)
Cash and Restricted Cash - Beginning of Year	209,324	85,890	106,750
Cash and Restricted Cash - End of Year	117,063	209,324	85,890
The Connecticut Light and Power Company
Operating Activities:
Net Income	410,852	377,717	376,726
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	301,188	278,557	249,352
Deferred Income Taxes	54,005	54,859	119,295
Uncollectible Expense	15,948	15,831	5,312
Pension, SERP and PBOP Expense, Net	12,761	8,943	9,909
Pension and PBOP Contributions	(24,000)	(41,150)	(2,500)
Regulatory (Under)/Over Recoveries, Net	(24,653)	(53,372)	(8,017)
Amortization of Regulatory Assets, Net	51,621	129,021	83,166
Other	(80,266)	(69,786)	(42,973)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(52,746)	(67,334)	(47,768)
Fuel, Materials, Supplies and REC Inventory	(6,171)	3,909	3,612
Taxes Receivable/Accrued, Net	(23,089)	8,954	(9,688)
Accounts Payable	102,344	(76,924)	48,032
Other Current Assets and Liabilities, Net	(11,350)	18,846	21,860
Net Cash Flows Provided by Operating Activities	726,444	588,071	806,318
Investing Activities:
Investments in Property, Plant and Equipment	(917,532)	(864,136)	(824,383)
Other Investing Activities	714	209	236
Net Cash Flows Used in Investing Activities	(916,818)	(863,927)	(824,147)
Financing Activities:
Cash Dividends on Common Shares	(341,800)	(60,000)	(254,800)
Cash Dividends on Preferred Stock	(5,559)	(5,559)	(5,559)
(Decrease)/Increase in Notes Payable to Eversource Parent	63,800	(69,500)	(10,600)
Issuance of Long-Term Debt	500,000	500,000	525,000
Retirement of Long-Term Debt	(250,000)	(300,000)	(250,000)
Capital Contributions from Eversource Parent	125,000	300,000	0
Other Financing Activities	12,291	(7,091)	15,004
Net Cash Flows Provided by/(Used in) Financing Activities	103,732	357,850	19,045
Net (Decrease)/Increase in Cash and Restricted Cash	(86,642)	81,994	1,216
Cash and Restricted Cash - Beginning of Year	91,613	9,619	8,403
Cash and Restricted Cash - End of Year	4,971	91,613	9,619
NSTAR Electric Company
Operating Activities:
Net Income	431,956	383,090	374,726
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	296,500	276,372	274,008
Deferred Income Taxes	27,107	41,438	110,499
Uncollectible Expense	25,079	22,279	21,252
Pension, SERP and PBOP Expense, Net	(12,399)	(21,521)	(9,509)
Pension and PBOP Contributions	(6,359)	(61,751)	(90,721)
Regulatory (Under)/Over Recoveries, Net	(60,863)	149,647	(20,009)
Amortization of Regulatory Assets, Net	103,735	46,654	33,831
Other	(78,220)	(65,523)	(24,872)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(11,087)	(26,403)	(50,896)
Fuel, Materials, Supplies and REC Inventory	(9,858)	(18,685)	(24,610)
Taxes Receivable/Accrued, Net	14,147	(33,900)	39,205
Accounts Payable	(22,659)	37,140	(20,421)
Other Current Assets and Liabilities, Net	1,194	51,674	26,849
Net Cash Flows Provided by Operating Activities	698,273	780,511	639,332
Investing Activities:
Investments in Property, Plant and Equipment	(861,391)	(725,766)	(719,623)
Other Investing Activities	86	58	(3,552)
Net Cash Flows Used in Investing Activities	(861,305)	(725,708)	(723,175)
Financing Activities:
Cash Dividends on Common Shares	(181,800)	(228,000)	(272,000)
Cash Dividends on Preferred Stock	(1,960)	(1,960)	(1,960)
Increase/(Decrease) in Notes Payable	(268,000)	44,500	56,500
Increase in Notes Payable to Eversource Parent	30,300	0	0
Issuance of Long-Term Debt	400,000	0	700,000
Retirement of Long-Term Debt	0	0	(400,000)
Capital Contributions from Eversource Parent	180,000	130,500	2,300
Other Financing Activities	(3,855)	108	(1,796)
Net Cash Flows Provided by/(Used in) Financing Activities	154,685	(54,852)	83,044
Net (Decrease)/Increase in Cash and Restricted Cash	(8,347)	(49)	(799)
Cash and Restricted Cash - Beginning of Year	14,659	14,708	15,507
Cash and Restricted Cash - End of Year	6,312	14,659	14,708
Public Service Company of New Hampshire
Operating Activities:
Net Income	134,048	115,876	135,996
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	93,737	92,055	128,192
Deferred Income Taxes	15,917	35,924	63,883
Uncollectible Expense	6,726	6,383	6,704
Pension, SERP and PBOP Expense, Net	417	754	1,368
Pension and PBOP Contributions	(15,400)	0	(800)
Regulatory (Under)/Over Recoveries, Net	(26,288)	(27,264)	(30,788)
Amortization of Regulatory Assets, Net	57,732	80,978	(16,577)
Other	(28,228)	(15,363)	(16,813)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(210)	(19,307)	(22,055)
Fuel, Materials, Supplies and REC Inventory	1,902	16,928	5,519
Taxes Receivable/Accrued, Net	25,374	(19,970)	339
Accounts Payable	12,281	(10,147)	29,453
Other Current Assets and Liabilities, Net	(3,573)	3,028	16,463
Net Cash Flows Provided by Operating Activities	274,435	259,875	300,884
Investing Activities:
Investments in Property, Plant and Equipment	(308,993)	(323,910)	(312,720)
Proceeds from the Sale of PSNH Generation Assets	0	193,924	0
Proceeds from the Sale of Property	0	4,782	0
Other Investing Activities	1,023	437	199
Net Cash Flows Used in Investing Activities	(307,970)	(124,767)	(312,521)
Financing Activities:
Cash Dividends on Common Shares	(271,000)	(150,000)	(23,900)
(Decrease)/Increase in Notes Payable to Eversource Parent	(30,000)	(205,900)	102,000
(Repayments)/Issuance of Rate Reduction Bonds	(52,332)	635,663	0
Return of Capital	0	(530,000)	0
Issuance of Long-Term Debt	300,000	0	0
Retirement of Long-Term Debt	(150,000)	(199,250)	(70,000)
Capital Contributions from Eversource Parent	225,000	365,000	0
Other Financing Activities	(4,168)	(89)	(225)
Net Cash Flows Provided by/(Used in) Financing Activities	17,500	(84,576)	7,875
Net (Decrease)/Increase in Cash and Restricted Cash	(16,035)	50,532	(3,762)
Cash and Restricted Cash - Beginning of Year	52,723	2,191	5,953
Cash and Restricted Cash - End of Year	$ 36,688	$ 52,723	$ 2,191

XML

EMPLOYEE BENEFITS

12 Months Ended

Dec. 31, 2019

Postemployment Benefits [Abstract]

EMPLOYEE BENEFITS

EMPLOYEE BENEFITS

A.     Pension Benefits and Postretirement Benefits Other Than Pension

Eversource provides defined benefit retirement plans (Pension Plans) that cover eligible employees and are subject to the provisions of ERISA, as amended by the Pension Protection Act of 2006. Eversource's policy is to annually fund the Pension Plans in an amount at least equal to an amount that will satisfy all federal funding requirements. In addition to the Pension Plans, Eversource maintains non-qualified defined benefit retirement plans (SERP Plans) which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees.

Eversource also provides defined benefit postretirement plans (PBOP Plans) that provide life insurance and a health reimbursement arrangement created for the purpose of reimbursing retirees and dependents for health insurance premiums and certain medical expenses to eligible employees that meet certain age and service eligibility requirements. The benefits provided under the PBOP Plans are not vested, and the Company has the right to modify any benefit provision subject to applicable laws at that time. Eversource annually funds postretirement costs through tax deductible contributions to external trusts.

The Pension, SERP and PBOP Plans cover eligible employees, including, among others, employees of the regulated companies. Because the regulated companies recover retiree benefit costs from customers through rates, regulatory assets are recorded in lieu of recording an adjustment to Accumulated Other Comprehensive Income/(Loss) as an offset to the funded status of the Pension, SERP and PBOP Plans.  Regulatory accounting is also applied to the portions of the Eversource Service retiree benefit costs that support the regulated companies, as these costs are also recovered from customers.  Adjustments to the Pension, SERP and PBOP Plans' funded status for the unregulated companies are recorded on an after-tax basis to Accumulated Other Comprehensive Income/(Loss).  For further information, see Note 2, "Regulatory Accounting," and Note 17, "Accumulated Other Comprehensive Income/(Loss)," to the financial statements.  

Funded Status:  The Pension, SERP and PBOP Plans are accounted for under the multiple-employer approach, with each operating company's balance sheet reflecting its share of the funded status of the plans.  Although Eversource maintains marketable securities in a benefit trust, the SERP Plans do not contain any assets.  For further information, see Note 5, "Marketable Securities," to the financial statements.  The following tables provide information on the plan benefit obligations, fair values of plan assets, and funded status:  

	Pension and SERP
	As of December 31,
	2019												2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Change in Benefit Obligation:
Benefit Obligation as of Beginning of Year	$	(5,520.0	)	$	(1,160.4	)	$	(1,236.5	)	$	(610.7	)	$	(5,936.5	)	$	(1,275.2	)	$	(1,351.0	)	$	(642.2	)
Service Cost	(67.7		)	(18.0		)	(14.6		)	(7.1		)	(84.8		)	(21.4		)	(17.4		)	(11.2		)
Interest Cost	(219.0		)	(45.7		)	(49.0		)	(24.0		)	(196.4		)	(41.8		)	(43.5		)	(22.0		)
Actuarial Gain/(Loss)	(815.3		)	(176.6		)	(181.0		)	(84.5		)	414.9			106.1			98.6			39.2
Benefits Paid - Pension	273.0			60.2			67.1			30.3			261.8			59.6			66.9			26.2
Benefits Paid - Lump Sum	20.0			—			12.9			—			14.2			—			7.1			—
Benefits Paid - SERP	7.3			0.3			0.1			0.4			6.8			0.3			0.3			0.2
Employee Transfers	—			8.9			3.7			3.0			—			12.0			2.5			(0.9		)
Benefit Obligation as of End of Year	$	(6,321.7	)	$	(1,331.3	)	$	(1,397.3	)	$	(692.6	)	$	(5,520.0	)	$	(1,160.4	)	$	(1,236.5	)	$	(610.7	)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of   Beginning of Year	$	4,573.9		$	918.4		$	1,222.1		$	506.6		$	4,739.5		$	963.0		$	1,260.8		$	539.5
Employer Contributions	112.5			24.0			0.4			15.4			185.6			41.2			56.5			—
Actual Return on Pension Plan Assets	575.2			112.9			150.0			62.9			(75.2		)	(14.2		)	(18.7		)	(7.6		)
Benefits Paid - Pension	(273.0		)	(60.2		)	(67.1		)	(30.3		)	(261.8		)	(59.6		)	(66.9		)	(26.2		)
Benefits Paid - Lump Sum	(20.0		)	—			(12.9		)	—			(14.2		)	—			(7.1		)	—
Employee Transfers	—			(8.9		)	(3.7		)	(3.0		)	—			(12.0		)	(2.5		)	0.9
Fair Value of Pension Plan Assets as of End of Year	$	4,968.6		$	986.2		$	1,288.8		$	551.6		$	4,573.9		$	918.4		$	1,222.1		$	506.6
Funded Status as of December 31st	$	(1,353.1	)	$	(345.1	)	$	(108.5	)	$	(141.0	)	$	(946.1	)	$	(242.0	)	$	(14.4	)	$	(104.1	)

As of December 31, 2019, there was a decrease in the discount rate used to calculate the pension funded status, which resulted in an increase to Eversource's pension liability of $813.1 million, which was partially offset by changes in actual plan experience and changes in other assumptions.

As of December 31, 2018, there was an increase in the discount rate used to calculate the pension funded status, which resulted in a decrease to Eversource's pension liability of approximately $465 million, which was partially offset by changes in actual plan experience and changes in other assumptions.

The pension and SERP Plans' funded status includes the current portion of the SERP liability totaling $8.7 million and $8.9 million as of December 31, 2019 and 2018, respectively, which is included in Other Current Liabilities on the balance sheets.  

As of December 31, 2019 and 2018, the accumulated benefit obligation for the Pension and SERP Plans is as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	5,963.4	$	1,205.4	$	1,340.8	$	646.7
2018	5,070.8		1,031.0		1,144.7		543.1

	PBOP
	As of December 31,
	2019												2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Change in Benefit Obligation:
Benefit Obligation as of Beginning of Year	$	(841.5	)	$	(161.7	)	$	(246.3	)	$	(91.9	)	$	(948.6	)	$	(178.4	)	$	(278.6	)	$	(101.1	)
Service Cost	(7.8		)	(1.4		)	(1.7		)	(0.7		)	(10.0		)	(1.9		)	(2.0		)	(1.1		)
Interest Cost	(32.7		)	(6.3		)	(9.5		)	(3.4		)	(30.7		)	(5.8		)	(8.7		)	(3.4		)
Actuarial Gain/(Loss)	(67.0		)	(13.4		)	(15.2		)	(3.1		)	102.5			14.4			28.4			8.6
Benefits Paid	50.0			10.8			15.4			5.6			45.3			10.1			14.5			4.9
Employee Transfers	—			(0.7		)	(1.0		)	0.5			—			(0.1		)	0.1			0.2
Benefit Obligation as of End of Year	$	(899.0	)	$	(172.7	)	$	(258.3	)	$	(93.0	)	$	(841.5	)	$	(161.7	)	$	(246.3	)	$	(91.9	)
Change in Plan Assets:
Fair Value of Plan Assets as of Beginning of Year	$	849.6		$	120.6		$	379.1		$	71.2		$	922.2		$	135.9		$	405.5		$	79.0
Actual Return on Plan Assets	127.0			17.1			57.0			10.0			(36.6		)	(5.2		)	(17.4		)	(2.9		)
Employer Contributions	9.3			—			6.0			—			9.3			—			5.2			—
Benefits Paid	(50.0		)	(10.8		)	(15.4		)	(5.6		)	(45.3		)	(10.1		)	(14.5		)	(4.9		)
Employee Transfers	—			(0.6		)	(2.3		)	0.4			—			—			0.3			—
Fair Value of Plan Assets as of End of Year	$	935.9		$	126.3		$	424.4		$	76.0		$	849.6		$	120.6		$	379.1		$	71.2
Funded Status as of December 31st	$	36.9		$	(46.4	)	$	166.1		$	(17.0	)	$	8.1		$	(41.1	)	$	132.8		$	(20.7	)

The Eversource PBOP funded status includes prepaid assets of $62.7 million and $33.4 million recorded in Other Long-Term Assets and liabilities of $25.8 million and $25.3 million included in Accrued Pension, SERP and PBOP on the balance sheets as of December 31, 2019 and 2018, respectively.

As of December 31, 2019, there was a decrease in the discount rate used to calculate the PBOP funded status, which resulted in an increase to the Eversource PBOP liability of $88.6 million. As of December 31, 2018, there was an increase in the discount rate used to calculate the funded status, which resulted in a decrease to the Eversource PBOP liability of approximately $88 million.

The following actuarial assumptions were used in calculating the Pension, SERP and PBOP Plans' year end funded status:

	Pension and SERP							PBOP
	As of December 31,							As of December 31,
		2019			2018			2019			2018
Discount Rate		3.04%	—	3.35%	4.22%	—	4.45%	3.26%	—	3.28%	4.38%	—	4.41%
Compensation/Progression Rate		3.50%	—	4.00%	3.50%	—	4.00%	N/A

For the Eversource Service PBOP Plan, the health care cost trend rate is not applicable. For the Aquarion PBOP Plan, the health care trend rate is a range of 3.5 percent to 6.5 percent, with an ultimate rate of 3.5 percent to 5 percent in 2019 and 2023, for post-65 and pre-65 retirees, respectively.

Expense:  Eversource charges net periodic benefit expense/(income) for the Pension, SERP and PBOP Plans to its subsidiaries based on the actual participant demographic data for each subsidiary's participants.  The actual investment return in the trust is allocated to each of the subsidiaries annually in proportion to the investment return expected to be earned during the year. The Company utilizes the spot rate methodology to estimate the discount rate for the service and interest cost components of benefit expense, which provides a more precise measurement by matching projected cash flows to the corresponding spot rates on the yield curve.

The components of net periodic benefit expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets for future recovery, are shown below. The service cost component of net periodic benefit expense/(income), less the capitalized portion, is included in Operations and Maintenance expense on the statements of income.  The remaining components of net periodic benefit expense/(income), less the deferred portion, are included in Other Income, Net on the statements of income.  Pension, SERP and PBOP expense reflected in the statements of cash flows for CL&P, NSTAR Electric and PSNH does not include the intercompany allocations or the corresponding capitalized and deferred portion, as these amounts are cash settled on a short-term basis.

	Pension and SERP												PBOP
	For the Year Ended December 31, 2019												For the Year Ended December 31, 2019
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	67.7		$	18.0		$	14.6		$	7.1		$	7.8		$	1.4		$	1.7		$	0.7
Interest Cost	219.0			45.7			49.0			24.0			32.7			6.3			9.5			3.4
Expected Return on Plan Assets	(367.1		)	(73.2		)	(97.1		)	(40.7		)	(66.8		)	(9.2		)	(30.2		)	(5.4		)
Actuarial Loss	143.2			26.9			44.7			10.6			8.3			1.3			3.3			0.3
Prior Service Cost/(Credit)	0.9			—			0.3			—			(23.5		)	1.1			(16.9		)	0.4
Total Net Periodic Benefit Expense/(Income)	$	63.7		$	17.4		$	11.5		$	1.0		$	(41.5	)	$	0.9		$	(32.6	)	$	(0.6	)
Intercompany Allocations	N/A			$	8.5		$	8.0		$	2.3		N/A			$	(0.9	)	$	(1.2	)	$	(0.4	)

	Pension and SERP												PBOP
	For the Year Ended December 31, 2018												For the Year Ended December 31, 2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	84.8		$	21.4		$	17.4		$	11.2		$	10.0		$	1.9		$	2.0		$	1.1
Interest Cost	196.4			41.8			43.5			22.0			30.7			5.8			8.7			3.4
Expected Return on Plan Assets	(391.6		)	(79.1		)	(104.9		)	(43.6		)	(72.4		)	(10.4		)	(32.5		)	(6.0		)
Actuarial Loss	145.7			29.1			41.1			11.6			10.3			1.6			2.3			0.7
Prior Service Cost/(Credit)	4.3			1.1			0.2			0.4			(23.6		)	1.1			(16.9		)	0.5
Total Net Periodic Benefit Expense/(Income)	$	39.6		$	14.3		$	(2.7	)	$	1.6		$	(45.0	)	$	—		$	(36.4	)	$	(0.3	)
Intercompany Allocations	N/A			$	6.1		$	6.5		$	1.9		N/A			$	(1.0	)	$	(1.3	)	$	(0.4	)

	Pension and SERP												PBOP
	For the Year Ended December 31, 2017												For the Year Ended December 31, 2017
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	71.3		$	18.5		$	15.5		$	9.7		$	9.5		$	1.9		$	1.7		$	1.3
Interest Cost	188.0			41.6			42.7			21.2			27.1			5.3			8.7			3.0
Expected Return on Plan Assets	(334.1		)	(71.7		)	(87.6		)	(40.0		)	(63.7		)	(9.7		)	(28.6		)	(5.5		)
Actuarial Loss	135.2			27.7			41.1			11.6			9.1			1.0			3.4			0.6
Prior Service Cost/(Credit)	4.5			1.5			0.6			0.5			(21.6		)	1.1			(17.0		)	0.6
Total Net Periodic Benefit Expense/(Income)	$	64.9		$	17.6		$	12.3		$	3.0		$	(39.6	)	$	(0.4	)	$	(31.8	)	$	—
Intercompany Allocations	N/A			$	9.8		$	9.1		$	3.3		N/A			$	(0.7	)	$	(1.1	)	$	(0.5	)

The following actuarial assumptions were used to calculate Pension, SERP and PBOP expense amounts:

	Pension and SERP									PBOP
	For the Years Ended December 31,									For the Years Ended December 31,
	2019			2018			2017			2019			2018			2017
Discount Rate	2.63%	—	3.55%	3.85%	—	4.62%	3.20%	—	3.90%	3.85%	—	4.65%	3.28%	—	3.94%	3.48%	—	4.64%
Expected Long-Term Rate of Return	8.25%			8.25%			8.25%			8.25%			8.25%			8.25%
Compensation/Progression Rate	3.50%	—	4.00%	3.50%	—	4.00%	3.50%			N/A			N/A			N/A

For the Aquarion Pension and PBOP Plans, the expected long-term rate of return was 7 percent for the years ended December 31, 2019 and 2018. For the Aquarion PBOP Plan, the health care trend rate was a range of 3.5 percent to 6.75 percent for the year ended December 31, 2019, and 7 percent for the year ended December 31, 2018.

The following is a summary of the changes in plan assets and benefit obligations recognized in Regulatory Assets and Other Comprehensive Income (OCI) as well as amounts in Regulatory Assets and OCI that were reclassified as net periodic benefit expense during the years presented:

	Pension and SERP												PBOP
	Regulatory Assets						OCI						Regulatory Assets						OCI
	For the Years Ended December 31,												For the Years Ended December 31,
(Millions of Dollars)	2019			2018			2019			2018			2019			2018			2019			2018
Actuarial Losses/(Gains) Arising During the Year	$	591.6		$	48.6		$	15.4		$	0.7		$	4.6		$	6.4		$	2.3		$	(1.2	)
Actuarial Losses Reclassified as Net Periodic Benefit Expense	(137.8		)	(140.1		)	(5.4		)	(5.6		)	(8.0		)	(9.9		)	(0.3		)	(0.4		)
Actuarial Losses Securitized as Stranded Costs (1)	—			(36.7		)	—			—			—			(0.8		)	—			—
Prior Service Cost Arising During the Year	—			—			—			—			—			1.3			—			—
Prior Service (Cost)/Credit Reclassified as Net Periodic Benefit (Expense)/Income	(0.7		)	(3.9		)	(0.2		)	(0.4		)	25.1			23.6			(1.6		)	—
Prior Service Cost Securitized as Stranded Costs (1)	—			(0.1		)	—			—			—			(1.3		)	—			—

⁽¹⁾ These amounts were reclassified to securitized regulatory assets in connection with the divestiture of PSNH's generation business. For further information see Note 2, "Regulatory Accounting" to the financial statements.

The following is a summary of the remaining Regulatory Assets and Accumulated Other Comprehensive Income amounts that have not been recognized as components of net periodic benefit expense as of December 31, 2019 and 2018, as well as the amounts that are expected to be recognized as components in 2020:

	Regulatory Assets as of December 31,						Expected 2020 Expense/(Income)			AOCI as of December 31,				Expected 2020 Expense
(Millions of Dollars)	2019			2018						2019		2018
Pension and SERP
Actuarial Loss	$	2,261.4		$	1,807.6		$	190.3		$	90.8	$	80.8	$	7.2
Prior Service Cost	5.6			6.3			0.9			0.9		1.1		0.2
PBOP
Actuarial Loss	$	203.9		$	207.3		$	8.3		$	7.0	$	5.0	$	0.2
Prior Service (Credit)/Cost	(172.5		)	(197.6		)	(21.4		)	1.0		2.6		0.2

The difference between the actual return and calculated expected return on plan assets for the Pension and PBOP Plans is reflected as a component of unamortized actuarial gains or losses, which are recorded in Regulatory Assets or Accumulated Other Comprehensive Income/(Loss). Unamortized actuarial gains or losses are amortized as a component of pension and PBOP expense over the estimated average future employee service period.

Estimated Future Benefit Payments:  The following benefit payments, which reflect expected future service, are expected to be paid by the Pension, SERP and PBOP Plans:

(Millions of Dollars)	2020		2021		2022		2023		2024		2025 - 2029
Pension and SERP	$	320.1	$	328.7	$	337.5	$	346.5	$	352.4	$	1,813.1
PBOP	58.1		57.9		57.3		56.8		56.2		264.7

Eversource Contributions:   Based on the current status of the Pension Plans and federal pension funding requirements, Eversource currently expects to make contributions of $105.0 million in 2020, of which $23.2 million and $19.5 million will be contributed by CL&P and PSNH, respectively.  The remaining $57.3 million is expected to be contributed by other Eversource subsidiaries, primarily Eversource Service. Eversource currently estimates contributing $2.9 million to the PBOP Plans in 2020.

Fair Value of Pension and PBOP Plan Assets:  Pension and PBOP funds are held in external trusts.  Trust assets, including accumulated earnings, must be used exclusively for Pension and PBOP payments.  Eversource's investment strategy for its Pension and PBOP Plans is to maximize the long-term rates of return on these plans' assets within an acceptable level of risk.  The investment strategy for each asset category includes a diversification of asset types, fund strategies and fund managers and it establishes target asset allocations that are routinely reviewed and periodically rebalanced.  PBOP assets are comprised of assets held in the PBOP Plan trust, as well as specific assets within the Pension Plan trust (401(h) assets).  The investment policy and strategy of the 401(h) assets is consistent with that of the defined benefit pension plan. Eversource's expected long-term rates of return on Pension and PBOP Plan assets are based on target asset allocation assumptions and related expected long-term rates of return.  In developing its expected long-term rate of return assumptions for the Pension and PBOP Plans, Eversource evaluated input from consultants, as well as long-term inflation assumptions and historical returns. Management has assumed long-term rates of return of 8.25 percent for the Eversource Service Pension and PBOP Plan assets and a 7 percent long-term rate of return for the Aquarion Plans to estimate its 2020 Pension and PBOP costs.

These long-term rates of return are based on the assumed rates of return for the target asset allocations as follows:

	As of December 31,
	2019				2018
	Eversource Pension Plan and Tax-Exempt Assets Within PBOP Plan				Eversource Pension Plan and Tax-Exempt Assets Within PBOP Plan
	Target Asset Allocation		Assumed Rate of Return		Target Asset Allocation		Assumed Rate of Return
Equity Securities:
United States	15.0	%	8.5	%	15.0	%	8.5	%
Global	10.0	%	8.75	%	10.0	%	8.75	%
Non-United States	8.0	%	8.5	%	8.0	%	8.5	%
Emerging Markets	4.0	%	10.0	%	4.0	%	10.0	%
Debt Securities:
Fixed Income	13.0	%	4.0	%	13.0	%	4.0	%
Public High Yield Fixed Income	4.0	%	6.5	%	4.0	%	6.5	%
Private Debt	15.0	%	9.0	%	15.0	%	9.0	%
Private Equity	15.0	%	12.0	%	15.0	%	12.0	%
Real Assets	16.0	%	7.5	%	16.0	%	7.5	%

The taxable assets within the Eversource PBOP Plan have a target asset allocation of 70 percent equity securities and 30 percent fixed income securities. The target asset allocation for the Aquarion Pension Plan is 54 percent equity, 36 percent debt and 10 percent other. The target asset allocation for the Aquarion PBOP Plan is 54 percent equity, 41 percent debt and 5 percent other.

The following table presents, by asset category, the Pension and PBOP Plan assets recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:  

	Pension Plan
	Fair Value Measurements as of December 31,
(Millions of Dollars)	2019									2018
Asset Category:	Level 1		Level 2		Uncategorized		Total			Level 1		Level 2		Uncategorized		Total
Equity Securities (1)	$	592.6	$	—	$	1,349.9	$	1,942.5		$	443.4	$	—	$	1,377.8	$	1,821.2
Fixed Income (2)	99.4		303.0		1,222.8		1,625.2			85.5		160.8		1,265.5		1,511.8
Private Equity	16.9		—		971.4		988.3			6.1		—		834.0		840.1
Real Assets (3)	58.7		—		615.0		673.7			62.9		—		569.1		632.0
Total	$	767.6	$	303.0	$	4,159.1	$	5,229.7		$	597.9	$	160.8	$	4,046.4	$	4,805.1
Less:  401(h) PBOP Assets (4)							(261.1		)							(231.2		)
Total Pension Assets							$	4,968.6								$	4,573.9

	PBOP Plan
	Fair Value Measurements as of December 31,
(Millions of Dollars)	2019								2018
Asset Category:	Level 1		Level 2		Uncategorized		Total		Level 1		Level 2		Uncategorized		Total
Equity Securities (1)	$	158.0	$	—	$	187.0	$	345.0	$	91.9	$	—	$	210.5	$	302.4
Fixed Income (2)	15.8		39.6		148.1		203.5		22.0		40.3		123.0		185.3
Private Equity	—		—		26.5		26.5		—		—		32.7		32.7
Real Assets (3)	51.2		—		48.6		99.8		27.5		—		70.5		98.0
Total	$	225.0	$	39.6	$	410.2	$	674.8	$	141.4	$	40.3	$	436.7	$	618.4
Add:  401(h) PBOP Assets (4)							261.1								231.2
Total PBOP Assets							$	935.9							$	849.6

⁽¹⁾   United States, Global, Non-United States and Emerging Markets equity securities that are uncategorized include investments in commingled funds and hedge funds that are overlaid with equity index swaps and futures contracts.

⁽²⁾ Fixed Income investments that are uncategorized include investments in commingled funds, fixed income funds that invest in a variety of opportunistic and fixed income strategies, and hedge funds that are overlaid with fixed income futures.  

⁽³⁾   Real assets include real estate funds and hedge funds.

⁽⁴⁾   The assets of the Pension Plan include a 401(h) account that has been allocated to provide health and welfare postretirement benefits under the PBOP Plan.

The Company values assets based on observable inputs when available.  Equity securities, exchange traded funds and futures contracts classified as Level 1 in the fair value hierarchy are priced based on the closing price on the primary exchange as of the balance sheet date.

Fixed income securities, such as government issued securities and corporate bonds, are included in Level 2 and are valued using pricing models, quoted prices of securities with similar characteristics or discounted cash flows.  The pricing models utilize observable inputs such as recent trades for the same or similar instruments, yield curves, discount margins and bond structures. Swaps are valued using pricing models that incorporate interest rates and equity and fixed income index closing prices to determine a net present value of the cash flows.  

Certain investments, such as commingled funds, private equity investments, real estate funds and hedge funds are valued using the net asset value (NAV) as a practical expedient. These investments are structured as investment companies offering shares or units to multiple investors for the purpose of providing a return. Commingled funds are recorded at NAV provided by the asset manager, which is based on the market prices of the underlying equity securities.  Private Equity investments, Fixed Income partnership funds and Real Assets are valued using the NAV provided by the partnerships, which are based on discounted cash flows of the underlying investments, real estate appraisals or public market comparables of the underlying investments, or the NAV of underlying assets held in hedge funds. Assets valued at NAV are uncategorized in the fair value hierarchy.Defined Contribution Plans

Eversource maintains defined contribution plans on behalf of eligible participants.  The Eversource 401k Plan provides for employee and employer contributions up to statutory limits.  For eligible employees, the Eversource 401k Plan provides employer matching contributions of either 100 percent up to a maximum of three percent of eligible compensation or 50 percent up to a maximum of eight percent of eligible compensation. The Eversource 401k Plan also contains a K-Vantage feature for the benefit of eligible participants, which provides an additional annual employer contribution based on age and years of service.  K-Vantage participants are not eligible to actively participate in the Eversource Pension Plan.

The total Eversource 401k Plan employer matching contributions, including the K-Vantage contributions, were as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	41.6	$	5.5	$	10.3	$	3.5
2018	38.4		5.0		9.7		3.3
2017	34.5		4.6		8.5		3.7

Share-Based Payments

Share-based compensation awards are recorded using a fair-value based method at the date of grant.  Eversource, CL&P, NSTAR Electric and PSNH record compensation expense related to these awards, as applicable, for shares issued or sold to their respective employees and officers, as well as for the allocation of costs associated with shares issued or sold to Eversource's service company employees and officers that support CL&P, NSTAR Electric and PSNH.  

Eversource Incentive Plans:  Eversource maintains long-term equity-based incentive plans in which Eversource, CL&P, NSTAR Electric and PSNH employees, officers and board members are eligible to participate.  The incentive plans authorize Eversource to grant up to 6,700,000 new shares for various types of awards, including RSUs and performance shares, to eligible employees, officers, and board members. As of December 31, 2019 and 2018, Eversource had 3,302,526 and 3,720,650 common shares, respectively, available for issuance under these plans.

Eversource accounts for its various share-based plans as follows:

• RSUs - Eversource records compensation expense, net of estimated forfeitures, on a straight-line basis over the requisite service period based upon the fair value of Eversource's common shares at the date of grant.  The par value of RSUs is reclassified to Common Stock from Capital Surplus, Paid In as RSUs become issued as common shares.

• Performance Shares - Eversource records compensation expense, net of estimated forfeitures, on a straight-line basis over the requisite service period.  Performance shares vest based upon the extent to which Company goals are achieved.  Vesting of outstanding performance shares is based upon both the Company's EPS growth over the requisite service period and the total shareholder return as compared to the Edison Electric Institute (EEI) Index during the requisite service period.  The fair value of performance shares is determined at the date of grant using a lattice model.

RSUs:  Eversource granted RSUs under the annual long-term incentive programs that are subject to three-year graded vesting schedules for employees, and one-year graded vesting schedules, or immediate vesting, for board members.  RSUs are paid in shares, reduced by amounts sufficient to satisfy withholdings for income taxes, subsequent to vesting.  A summary of RSU transactions is as follows:

	RSUs (Units)		Weighted Average Grant-Date Fair Value
Outstanding as of December 31, 2018	782,365		$	50.25
Granted	271,144		$	67.91
Shares Issued	(263,219	)	$	55.34
Forfeited	(16,127	)	$	63.31
Outstanding as of December 31, 2019	774,163		$	54.43

The weighted average grant-date fair value of RSUs granted for the years ended December 31, 2019, 2018 and 2017 was $67.91, $56.69 and $55.97, respectively.  As of December 31, 2019 and 2018, the number and weighted average grant-date fair value of unvested RSUs was 439,293 and $63.06 per share, and 424,119 and $56.57 per share, respectively.  During 2019, there were 236,359 RSUs at a weighted average grant-date fair value of $57.47 per share that vested during the year and were either paid or deferred.  As of December 31, 2019, 334,870 RSUs were fully vested and deferred and an additional 417,328 are expected to vest.  

Performance Shares:  Eversource granted performance shares under the annual long-term incentive programs that vest based upon the extent to which Company goals are achieved at the end of three-year performance measurement periods.  Performance shares are paid in shares, after the performance measurement period.  A summary of performance share transactions is as follows:

	Performance Shares (Units)		Weighted Average Grant-Date Fair Value
Outstanding as of December 31, 2018	499,564		$	56.08
Granted	165,022		$	68.33
Shares Issued	(162,959	)	$	55.69
Forfeited	(14,720	)	$	58.20
Outstanding as of December 31, 2019	486,907		$	60.30

The weighted average grant-date fair value of performance shares granted for the years ended December 31, 2019, 2018 and 2017 was $68.33, $56.77 and $55.70, respectively.  As of December 31, 2019 and 2018, the number and weighted average grant-date fair value of unvested performance shares was 427,894 and $60.38 per share, and 366,995 and $56.17 per share, respectively.  During 2019, there were 88,664 performance shares at a weighted average grant-date fair value of $58.13 per share that vested during the year and were either paid or deferred.  As of December 31, 2019, 59,013 performance shares were fully vested and deferred.

Compensation Expense: The total compensation expense and associated future income tax benefits recognized by Eversource, CL&P, NSTAR Electric and PSNH for share-based compensation awards were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Compensation Expense	$	27.3	$	21.4	$	19.7
Future Income Tax Benefit	7.0		5.4		8.0

	For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Compensation Expense	$	9.8	$	9.7	$	3.3	$	7.8	$	7.7	$	2.9	$	7.0	$	7.0	$	3.2
Future Income Tax Benefit	2.5		2.5		0.8		2.0		1.9		0.7		2.9		2.8		1.3

As of December 31, 2019, there was $24.4 million of total unrecognized compensation expense related to nonvested share-based awards for Eversource, including $5.3 million for CL&P, $5.3 million for NSTAR Electric and $2.1 million for PSNH.  This cost is expected to be recognized ratably over a weighted-average period of 1.75 years for Eversource, 1.79 years for CL&P and NSTAR Electric, and 1.78 years for PSNH.

An income tax rate of 25 percent was used to estimate the tax effect on total share-based payments determined under the fair-value based method for all awards.  Beginning in 2019, the Company began issuing treasury shares to settle fully vested RSUs and performance shares under the Company's incentive plans.

For the years ended December 31, 2019, 2018 and 2017, excess tax benefits associated with the distribution of stock compensation awards reduced income tax expense by $1.5 million, $1.5 million, and $2.9 million, respectively, which increased cash flows from operating activities on the statements of cash flows.

Other Retirement Benefits

Eversource provides retirement and other benefits for certain current and past company officers.  These benefits are accounted for on an accrual basis and expensed over a period equal to the service lives of the employees.  The actuarially-determined liability for these benefits is included in Other Current and Long-Term Liabilities on the balance sheets. The related expense, which includes the allocation of expense associated with Eversource's service company officers that support CL&P, NSTAR Electric and PSNH, is included in Operations and Maintenance Expense on the income statements. The liability and expense amounts are as follows:

Eversource (Millions of Dollars)	As of and For the Years Ended December 31,
	2019		2018		2017
Actuarially-Determined Liability	$	52.0	$	49.1	$	53.4
Other Retirement Benefits Expense	2.7		2.7		2.8

	As of and For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Actuarially-Determined   Liability	$	0.2	$	0.1	$	1.7	$	0.3	$	0.1	$	1.7	$	0.3	$	0.1	$	1.9
Other Retirement Benefits   Expense	1.0		0.9		0.4		1.1		1.1		0.4		1.0		1.0		0.5

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EMPLOYEE BENEFITS - Share-Based Payments Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted in incentive plan (up to) (in shares)	6,700,000
Shares available for issuance under incentive plan (in shares)	3,302,526	3,720,650
Shares outstanding (in shares)	439,293
Weighted average grant date fair value of restricted stock units (in dollars per share)	$ 57.47
Total unrecognized compensation expense	$ 24.4
Tax effect on total share-based payments (in percentage)	25.00%
Excess tax benefit	$ 1.5	$ 1.5	$ 2.9
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in dollars per share)	$ 67.91	$ 56.69	$ 55.97
Shares outstanding (in shares)		424,119
Weighted average shares outstanding (in dollars per share)	$ 63.06	$ 56.57
Restricted stock units available (in shares)	236,359
Restricted stock unit fully vested (in shares)	334,870
Additional restricted stock unit expected to vest (in shares)	417,328
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in dollars per share)	$ 68.33	$ 56.77	$ 55.70
Shares outstanding (in shares)	427,894	366,995
Weighted average shares outstanding (in dollars per share)	$ 60.38	$ 56.17
Restricted stock units available (in shares)	88,664
Weighted average grant date fair value of restricted stock units (in dollars per share)	$ 58.13
Restricted stock unit fully vested (in shares)	59,013
CL&P
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unrecognized compensation expense	$ 5.3
Period for recognition	1 year 8 months 44 days
NSTAR Electric
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unrecognized compensation expense	$ 5.3
Period for recognition	1 year 9 months 14 days
Eversource
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period for recognition	1 year 9 months
PSNH
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total unrecognized compensation expense	$ 2.1
Period for recognition	1 year 9 months 10 days
Employee
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period of graded vesting schedule under long-term incentive program	3 years
Board Members
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Period of graded vesting schedule under long-term incentive program	1 year

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PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

12 Months Ended

Dec. 31, 2019

Property, Plant and Equipment [Abstract]

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

Utility property, plant and equipment is recorded at original cost.  Original cost includes materials, labor, construction overheads and AFUDC for regulated property.  The cost of repairs and maintenance is charged to Operations and Maintenance expense as incurred.  

The following tables summarize property, plant and equipment by asset category:

Eversource	As of December 31,
(Millions of Dollars)	2019			2018
Distribution - Electric	$	15,880.0		$	15,071.1
Distribution - Natural Gas	3,931.1			3,546.2
Transmission - Electric	10,958.4			10,153.9
Distribution - Water	1,726.5			1,639.8
Solar	200.2			164.1
Utility	32,696.2			30,575.1
Other (1)	1,025.6			778.6
Property, Plant and Equipment, Gross	33,721.8			31,353.7
Less:  Accumulated Depreciation
Utility	(7,483.5		)	(7,126.2		)
Other	(387.4		)	(336.7		)
Total Accumulated Depreciation	(7,870.9		)	(7,462.9		)
Property, Plant and Equipment, Net	25,850.9			23,890.8
Construction Work in Progress	1,734.6			1,719.6
Total Property, Plant and Equipment, Net	$	27,585.5		$	25,610.4

	As of December 31,
	2019									2018
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Distribution - Electric	$	6,485.5		$	7,163.7		$	2,271.1		$	6,176.4		$	6,756.4		$	2,178.6
Transmission - Electric	5,043.0			4,411.9			1,498.7			4,700.5			4,065.9			1,338.7
Solar	—			200.2			—			—			164.1			—
Property, Plant and Equipment, Gross	11,528.5			11,775.8			3,769.8			10,876.9			10,986.4			3,517.3
Less:  Accumulated Depreciation	(2,385.7		)	(2,895.3		)	(799.9		)	(2,302.6		)	(2,702.0		)	(772.9		)
Property, Plant and Equipment, Net	9,142.8			8,880.5			2,969.9			8,574.3			8,284.4			2,744.4
Construction Work in Progress	483.0			592.3			159.6			335.4			510.3			135.7
Total Property, Plant and Equipment, Net	$	9,625.8		$	9,472.8		$	3,129.5		$	8,909.7		$	8,794.7		$	2,880.1

⁽¹⁾  These assets are primarily comprised of computer software, hardware and equipment at Eversource Service and buildings at The Rocky River Realty Company.

In 2019, Eversource recorded an impairment charge for the NPT project costs, which had been recorded within both Construction Work in Progress and the Transmission - Electric asset categories. For further information regarding the impairment of NPT, see Note 1D, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements.

Depreciation of utility assets is calculated on a straight-line basis using composite rates based on the estimated remaining useful lives of the various classes of property (estimated useful life for PSNH distribution and the water utilities).  The composite rates, which are subject to approval by the appropriate state regulatory agency, include a cost of removal component, which is collected from customers over the lives of the plant assets and is recognized as a regulatory liability.  Depreciation rates are applied to property from the time it is placed in service.

Upon retirement from service, the cost of the utility asset is charged to the accumulated provision for depreciation.  The actual incurred removal costs are applied against the related regulatory liability.  

The depreciation rates for the various classes of utility property, plant and equipment aggregate to composite rates as follows:

(Percent)	2019		2018		2017
Eversource	3.0	%	2.9	%	3.0	%
CL&P	2.8	%	2.8	%	2.8	%
NSTAR Electric	2.8	%	2.8	%	2.9	%
PSNH	2.8	%	2.8	%	3.1	%

The following table summarizes average remaining useful lives of depreciable assets:

	As of December 31, 2019
(Years)	Eversource	CL&P	NSTAR Electric	PSNH
Distribution - Electric	34.3	35.3	33.7	33.2
Distribution - Natural Gas	43.2	—	—	—
Transmission - Electric	40.4	36.8	44.9	42.1
Distribution - Water	33.5	—	—	—
Solar	24.2	—	24.2	—
Other (1)	11.2	—	—	—

⁽¹⁾ 

The estimated useful life of computer software, hardware and equipment primarily ranges from 5 to 15 years and of buildings is 40 years.

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EMPLOYEE BENEFITS - Schedule of Components of Net Periodic Benefit Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost	$ 67.7	$ 84.8	$ 71.3
Interest Cost	219.0	196.4	188.0
Expected Return on Plan Assets	(367.1)	(391.6)	(334.1)
Actuarial Loss	143.2	145.7	135.2
Prior Service Cost/(Credit)	0.9	4.3	4.5
Total Net Periodic Benefit Income	63.7	39.6	64.9
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost	7.8	10.0	9.5
Interest Cost	32.7	30.7	27.1
Expected Return on Plan Assets	(66.8)	(72.4)	(63.7)
Actuarial Loss	8.3	10.3	9.1
Prior Service Cost/(Credit)	(23.5)	(23.6)	(21.6)
Total Net Periodic Benefit Income	(41.5)	(45.0)	(39.6)
CL&P | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost	18.0	21.4	18.5
Interest Cost	45.7	41.8	41.6
Expected Return on Plan Assets	(73.2)	(79.1)	(71.7)
Actuarial Loss	26.9	29.1	27.7
Prior Service Cost/(Credit)	0.0	1.1	1.5
Total Net Periodic Benefit Income	17.4	14.3	17.6
Intercompany Allocations	8.5	6.1	9.8
CL&P | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost	1.4	1.9	1.9
Interest Cost	6.3	5.8	5.3
Expected Return on Plan Assets	(9.2)	(10.4)	(9.7)
Actuarial Loss	1.3	1.6	1.0
Prior Service Cost/(Credit)	1.1	1.1	1.1
Total Net Periodic Benefit Income	0.9	0.0	(0.4)
Intercompany Allocations	(0.9)	(1.0)	(0.7)
NSTAR Electric | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost	14.6	17.4	15.5
Interest Cost	49.0	43.5	42.7
Expected Return on Plan Assets	(97.1)	(104.9)	(87.6)
Actuarial Loss	44.7	41.1	41.1
Prior Service Cost/(Credit)	0.3	0.2	0.6
Total Net Periodic Benefit Income	11.5	(2.7)	12.3
Intercompany Allocations	8.0	6.5	9.1
NSTAR Electric | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost	1.7	2.0	1.7
Interest Cost	9.5	8.7	8.7
Expected Return on Plan Assets	(30.2)	(32.5)	(28.6)
Actuarial Loss	3.3	2.3	3.4
Prior Service Cost/(Credit)	(16.9)	(16.9)	(17.0)
Total Net Periodic Benefit Income	(32.6)	(36.4)	(31.8)
Intercompany Allocations	(1.2)	(1.3)	(1.1)
PSNH | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost	7.1	11.2	9.7
Interest Cost	24.0	22.0	21.2
Expected Return on Plan Assets	(40.7)	(43.6)	(40.0)
Actuarial Loss	10.6	11.6	11.6
Prior Service Cost/(Credit)	0.0	0.4	0.5
Total Net Periodic Benefit Income	1.0	1.6	3.0
Intercompany Allocations	2.3	1.9	3.3
PSNH | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Service Cost	0.7	1.1	1.3
Interest Cost	3.4	3.4	3.0
Expected Return on Plan Assets	(5.4)	(6.0)	(5.5)
Actuarial Loss	0.3	0.7	0.6
Prior Service Cost/(Credit)	0.4	0.5	0.6
Total Net Periodic Benefit Income	(0.6)	(0.3)	0.0
Intercompany Allocations	$ (0.4)	$ (0.4)	$ (0.5)

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EMPLOYEE BENEFITS - Schedule of Long-term Rates of Return on Pension and PBOP (Details)	Dec. 31, 2019	Dec. 31, 2018
United States
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	15.00%	15.00%
Assumed Rate of Return	8.50%	8.50%
Global
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	10.00%	10.00%
Assumed Rate of Return	8.75%	8.75%
Non-United States
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	8.00%	8.00%
Assumed Rate of Return	8.50%	8.50%
Emerging Markets
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	4.00%	4.00%
Assumed Rate of Return	10.00%	10.00%
Fixed Income
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	13.00%	13.00%
Assumed Rate of Return	4.00%	4.00%
Public High Yield Fixed Income
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	4.00%	4.00%
Assumed Rate of Return	6.50%	6.50%
Private Debt
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	15.00%	15.00%
Assumed Rate of Return	9.00%	9.00%
Private Equity
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	15.00%	15.00%
Assumed Rate of Return	12.00%	12.00%
Real Assets
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation	16.00%	16.00%
Assumed Rate of Return	7.50%	7.50%

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INVESTMENTS IN UNCONSOLIDATED AFFILIATES

12 Months Ended

Dec. 31, 2019

Equity Method Investments and Joint Ventures [Abstract]

INVESTMENTS IN UNCONSOLIDATED AFFILIATES

INVESTMENTS IN UNCONSOLIDATED AFFILIATES

Investments in entities that are not consolidated are included in long-term assets on the balance sheets and earnings impacts from these equity investments are included in Other Income, Net on the statements of income.  Eversource's investments included the following:

			Investment Balance as of December 31,
(Millions of Dollars)	Ownership Interest		2019		2018
Offshore Wind Business - North East Offshore and Bay State Wind	50	%	$	649.3	$	234.3
Natural Gas Pipeline - Algonquin Gas Transmission, LLC	15	%	127.8		155.0
Renewable Energy Investment Fund	90	%	72.4		54.1
Other	various		22.1		20.9
Total Investments in Unconsolidated Affiliates			$	871.6	$	464.3

For the years ended December 31, 2019, 2018 and 2017, Eversource had equity in earnings, net of impairment, of unconsolidated affiliates of $42.2 million, $3.8 million, and $27.4 million, respectively. Eversource received dividends from its equity method investees of $48.9 million, $22.3 million and $20.0 million, respectively, for the years ended December 31, 2019, 2018 and 2017.

Investments in affiliates where Eversource has the ability to exercise significant influence, but not control, over an investee are initially recognized as an equity method investment at cost. Any differences between the cost of an investment and the amount of underlying equity in net assets of an investee are considered basis differences, and are determined based upon the estimated fair values of the investee's identifiable assets and liabilities. The carrying amount of Eversource’s offshore wind investments exceeded its share of underlying equity in net assets by $240.3 million and $7.2 million, respectively, as of December 31, 2019 and 2018. As of December 31, 2019, these basis differences are primarily comprised of $168.3 million of equity method goodwill that is not being amortized, intangible assets for PPAs, which will be amortized over the term of the PPAs, and capitalized interest.

Offshore Wind Business: Eversource's offshore wind business includes ownership interests in North East Offshore and Bay State Wind, which together hold PPAs and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind projects, as well as offshore leases through BOEM. Eversource's offshore wind projects are being developed and constructed through a joint and equal partnership with Ørsted. On February 8, 2019, Eversource and Ørsted entered into an equal partnership to acquire key offshore wind assets in the Northeast. Eversource has a 50 percent ownership interest in North East Offshore, which holds the Revolution Wind and South Fork Wind projects, as well as a 257 square-mile lease off the coasts of Massachusetts and Rhode Island. Eversource also has a 50 percent ownership interest in Bay State Wind, which holds the Sunrise Wind project. Bay State Wind's separate 300-square-mile ocean lease is located approximately 25 miles south of the coast of Massachusetts adjacent to the North East Offshore area.

NSTAR Electric: As of December 31, 2019 and 2018, NSTAR Electric's investments included a 14.5 percent ownership interest in two companies that transmit hydro-electricity imported from the Hydro-Quebec system in Canada of $8.2 million and $7.6 million, respectively.

Impairment of Equity Method Investments: Equity method investments are assessed for impairment when conditions exist that indicate that the fair value of the investment is less than book value.  If the decline in value is considered to be other-than-temporary, the investment is written down to its estimated fair value, which establishes a new cost basis in the investment. Impairment evaluations involve a significant degree of judgment and estimation, including identifying circumstances that indicate an impairment may exist and developing undiscounted future cash flows.

During the year ended December 31, 2018, Eversource recorded an other-than-temporary impairment of $32.9 million within Other Income, Net on our statement of income, related to Access Northeast, a natural gas pipeline and storage project, which represented the full carrying value of our equity method investment. On April 1, 2019, pursuant to a provision in the partnership agreement jointly entered into by Eversource, Enbridge, Inc. and National Grid plc, through Algonquin Gas Transmission, LLC, the Access Northeast project was terminated.

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DERIVATIVE INSTRUMENTS - Unobservable Inputs Utilized (Details) - CL&P - Level 3 - $ / KWmo	Dec. 31, 2019	Dec. 31, 2018
Capacity Prices | Minimum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative measurement input	3.01	4.30
Capacity Prices | Maximum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative measurement input	7.34	7.44
Forward Reserve | Minimum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative measurement input	0.80	0.75
Forward Reserve | Maximum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative measurement input	1.90	1.78

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SHORT-TERM DEBT - Schedule of Debt (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Line of Credit Facility [Line Items]
Borrowings Outstanding	$ 889,084	$ 910,000
Eversource Parent Commercial Paper Program
Line of Credit Facility [Line Items]
Borrowings Outstanding	878,584	631,500
Commercial Paper | Eversource Parent Commercial Paper Program
Line of Credit Facility [Line Items]
Borrowings Outstanding	1,224,900	631,500
Available Borrowing Capacity	$ 225,100	$ 818,500
Weighted-Average Interest Rate (as a percentage)	1.98%	2.77%
Commercial Paper | NSTAR Electric
Line of Credit Facility [Line Items]
Borrowings Outstanding	$ 10,500	$ 278,500
Available Borrowing Capacity	$ 639,500	$ 371,500
Weighted-Average Interest Rate (as a percentage)	1.63%	2.50%

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INVESTMENTS IN UNCONSOLIDATED AFFILIATES - Summary of Investments (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affilitates	$ 871,633	$ 464,286
Offshore Wind Business - North East Offshore and Bay State Wind
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affilitates	$ 649,300	234,300
Natural Gas Pipeline - Algonquin Gas Transmission, LLC
Schedule of Equity Method Investments [Line Items]
Ownership interest	15.00%
Investments in unconsolidated affilitates	$ 127,800	155,000
Renewable Energy Investment Fund
Schedule of Equity Method Investments [Line Items]
Ownership interest	90.00%
Investments in unconsolidated affilitates	$ 72,400	54,100
Other
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affilitates	$ 22,100	$ 20,900

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PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION - Schedule of Aggregate Composite Depreciation Rates (Details)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Composite depreciation rate for plant in service	3.00%	2.90%	3.00%
CL&P
Property, Plant and Equipment [Line Items]
Composite depreciation rate for plant in service	2.80%	2.80%	2.80%
NSTAR Electric
Property, Plant and Equipment [Line Items]
Composite depreciation rate for plant in service	2.80%	2.80%	2.90%
PSNH
Property, Plant and Equipment [Line Items]
Composite depreciation rate for plant in service	2.80%	2.80%	3.10%

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REGULATORY ACCOUNTING - Narrative (Details) - USD ($)		3 Months Ended	12 Months Ended
	May 01, 2019	Mar. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jun. 27, 2019	Apr. 17, 2019	Apr. 16, 2019	Mar. 26, 2019	Nov. 16, 2018	May 08, 2018
Regulatory Assets [Line Items]
Deferred storm restoration costs			$ 5,514,700,000	$ 5,145,900,000
Amount of regulatory costs not yet approved			146,000,000.0	122,900,000
Other Income, Net			132,777,000	128,366,000	$ 107,913,000
Deferred Storm Restoration Costs
Regulatory Assets [Line Items]
Deferred storm restoration costs			126,000,000
Goodwill-related
Regulatory Assets [Line Items]
Deferred storm restoration costs			$ 331,500,000	348,400,000
Recovery period			40 years
Remaining amortization			20 years
PSNH
Regulatory Assets [Line Items]
Deferred storm restoration costs			$ 945,800,000	929,500,000
Amount of regulatory costs not yet approved			18,000,000.0	12,200,000
Equity return not recorded on the balance sheet			6,500,000	12,000,000.0
Other Income, Net			19,222,000	27,672,000	9,805,000
PSNH | Deferred Storm Restoration Costs
Regulatory Assets [Line Items]
Deferred storm restoration costs			16,000,000
Other Income, Net		$ 5,200,000	6,300,000	8,700,000
PSNH | Storm Costs
Regulatory Assets [Line Items]
Deferred storm restoration costs						$ 68,500,000			$ 38,100,000
PSNH | Goodwill-related
Regulatory Assets [Line Items]
Deferred storm restoration costs			0	0
CL&P
Regulatory Assets [Line Items]
Deferred storm restoration costs			1,735,900,000	1,630,700,000
Amount of regulatory costs not yet approved			51,800,000	42,100,000
Equity return not recorded on the balance sheet			500,000	700,000
Other Income, Net			17,531,000	22,663,000	22,991,000
CL&P | Deferred Storm Restoration Costs
Regulatory Assets [Line Items]
Deferred storm restoration costs			62,000,000
CL&P | Storm Costs
Regulatory Assets [Line Items]
Deferred storm restoration costs	$ 141,000,000.0						$ 141,000,000.0
Amount of regulatory costs not yet approved								$ 145,500,000		$ 153,000,000
Recovery period	6 years
CL&P | Goodwill-related
Regulatory Assets [Line Items]
Deferred storm restoration costs			0	0
NSTAR Electric
Regulatory Assets [Line Items]
Deferred storm restoration costs			1,535,600,000	1,438,200,000
Amount of regulatory costs not yet approved			55,700,000	49,300,000
Other Income, Net			44,577,000	53,066,000	$ 34,100,000
NSTAR Electric | Deferred Storm Restoration Costs
Regulatory Assets [Line Items]
Deferred storm restoration costs			48,000,000
NSTAR Electric | Goodwill-related
Regulatory Assets [Line Items]
Deferred storm restoration costs			$ 284,600,000	$ 299,100,000
Rate Reduction Bonds | PSNH
Regulatory Assets [Line Items]
Amount of securitized rate reduction bonds issued											$ 635,700,000

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MARKETABLE SECURITIES - Equity Securities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Equity securities	$ 45.7	$ 44.0
Amortized Cost	228.4	190.0
Pre-Tax Unrealized Gains	5.8	0.4
Pre-Tax Unrealized Losses	(0.1)	(4.0)
Fair Value	234.1	186.4
CYAPC and YAEC
Debt Securities, Available-for-sale [Line Items]
Equity securities	182.8	200.0
Marketable securities held in nuclear decommissioning trusts	198.1	143.9
Accounting Standards Update 2016-01
Debt Securities, Available-for-sale [Line Items]
Unrealized gains recorded in other income	$ 9.8
Unrealized losses recorded in other income		$ 4.3

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SCHEDULE I - FINANCIAL INFORMATION OF REGISTRANT - STATEMENT OF CASH FLOW (Details) - USD ($) $ in Thousands			3 Months Ended								12 Months Ended
	Dec. 30, 2019	Jun. 04, 2019	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating Activities:
Net Income			$ 251,900	$ 320,800	$ 33,300	$ 310,600	$ 233,200	$ 291,300	$ 244,600	$ 271,400	$ 916,572	$ 1,040,519	$ 995,515
Flows Provided by Operating Activities:
Equity in Earnings of Subsidiaries											(42,200)	(3,800)	(27,400)
Deferred Income Taxes											209,812	174,812	491,630
Other											(196,087)	(111,225)	(204,421)
Accounts Receivables from Subsidiaries											(98,716)	(141,433)	(117,155)
Taxes Receivable/Accrued, Net											(16,129)	(67,770)	52,284
Other Current Assets and Liabilities, Net											(11,603)	78,226	91,545
Net Cash Flows Provided by Operating Activities											2,009,577	1,830,543	1,996,202
Investing Activities:
Other Investing Activities											24,204	6,754	5,479
Net Cash Flows Used in Investing Activities											(3,274,288)	(2,437,046)	(3,230,516)
Financing Activities:
Issuance of Common Shares, Net of Issuance Costs	$ 425,400	$ 426,900									852,254	0	0
Cash Dividends on Common Shares											(663,239)	(640,110)	(602,083)
Issuance of Long-Term Debt											1,520,000	2,200,000	2,500,000
Retirement of Long-Term Debt											(801,078)	(1,050,330)	(745,000)
Increase/(Decrease) in Notes Payable											325,370	(379,310)	72,810
Other Financing Activities											(1,006)	(28,457)	(4,754)
Net Cash Flows Provided by/(Used in) Financing Activities											1,172,450	729,937	1,213,454
Cash, Cash Equivalents and Restricted Cash - Beginning of Year						108,068					108,068
Cash, Cash Equivalents and Restricted Cash - End of Year			15,432				108,068				15,432	108,068
Cash Paid/(Received) During the Year for:
Interest											532,400	503,200	419,100
Income Taxes											56,000	158,800	30,800
Eversource
Operating Activities:
Net Income											909,053	1,033,000	987,996
Flows Provided by Operating Activities:
Equity in Earnings of Subsidiaries											(1,001,526)	(1,049,748)	(993,063)
Cash Dividends Received from Subsidiaries											883,000	569,500	753,300
Deferred Income Taxes											13,382	20,032	37,867
Other											19,584	(31,093)	(36,052)
Accounts Receivables from Subsidiaries											7,105	(28,716)	29,405
Taxes Receivable/Accrued, Net											(605)	(20,207)	1,555
Accounts Payable to Subsidiaries											(4,099)	(9,817)	9,763
Other Current Assets and Liabilities, Net											(2,503)	2,553	7,536
Net Cash Flows Provided by Operating Activities											823,391	485,504	798,307
Investing Activities:
Capital Contributions to Subsidiaries											(1,039,000)	(955,700)	(1,156,731)
Return of Capital from Subsidiary											0	530,000	0
Increase in Notes Receivable from Subsidiaries											(218,100)	(158,210)	(192,100)
Other Investing Activities											(1,799)	(1,149)	1,484
Net Cash Flows Used in Investing Activities											(1,258,899)	(585,059)	(1,347,347)
Financing Activities:
Issuance of Common Shares, Net of Issuance Costs											852,254	0	0
Cash Dividends on Common Shares											(663,239)	(640,110)	(602,083)
Issuance of Long-Term Debt											0	1,550,000	1,200,000
Retirement of Long-Term Debt											(350,000)	(450,000)	0
Increase/(Decrease) in Notes Payable											593,370	(347,810)	(42,690)
Other Financing Activities											4,001	(12,455)	(5,759)
Net Cash Flows Provided by/(Used in) Financing Activities											436,386	99,625	549,468
Net Increase/(Decrease) in Cash and Cash Equivalents											878	70	428
Cash, Cash Equivalents and Restricted Cash - Beginning of Year						$ 591				$ 521	591	521	93
Cash, Cash Equivalents and Restricted Cash - End of Year			$ 1,469				$ 591				1,469	591	521
Cash Paid/(Received) During the Year for:
Interest											161,323	118,533	73,868
Income Taxes											$ (63,227)	$ (30,239)	$ (59,526)

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DIVIDEND RESTRICTIONS - Narrative (Details) $ in Millions	Dec. 31, 2019 USD ($)
Schedule of Restrictions on Retained Earnings [Line Items]
Consolidated total debt to total capital ratio (as a percentage)	0.65
Retained earnings subject to restrictions	$ 4,200.0
CL&P
Schedule of Restrictions on Retained Earnings [Line Items]
Retained earnings subject to restrictions	1,800.0
NSTAR Electric
Schedule of Restrictions on Retained Earnings [Line Items]
Retained earnings subject to restrictions	2,300.0
PSNH
Schedule of Restrictions on Retained Earnings [Line Items]
Retained earnings subject to restrictions	$ 490.3

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COMMON SHARES (Tables)

12 Months Ended

Dec. 31, 2019

Equity [Abstract]

Common Shares Authorized and Issued

The following table sets forth the Eversource parent common shares and the shares of common stock of CL&P, NSTAR Electric and PSNH that were authorized and issued, as well as the respective per share par values:  

	Shares
	Par Value		Authorized as of December 31, 2019 and 2018	Issued as of December 31,
				2019	2018
Eversource	$	5	380,000,000	345,858,402	333,878,402
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

Details of preferred stock not subject to mandatory redemption are as follows (in millions, except in redemption price and shares):

		Redemption Price Per Share		Shares Outstanding as of December 31,		As of December 31,
Series				2019	2018	2019			2018
CL&P
$1.90	Series of 1947	$	52.50	163,912	163,912	$	8.2		$	8.2
$2.00	Series of 1947	$	54.00	336,088	336,088	16.8			16.8
$2.04	Series of 1949	$	52.00	100,000	100,000	5.0			5.0
$2.20	Series of 1949	$	52.50	200,000	200,000	10.0			10.0
3.90%	Series of 1949	$	50.50	160,000	160,000	8.0			8.0
$2.06	Series E of 1954	$	51.00	200,000	200,000	10.0			10.0
$2.09	Series F of 1955	$	51.00	100,000	100,000	5.0			5.0
4.50%	Series of 1956	$	50.75	104,000	104,000	5.2			5.2
4.96%	Series of 1958	$	50.50	100,000	100,000	5.0			5.0
4.50%	Series of 1963	$	50.50	160,000	160,000	8.0			8.0
5.28%	Series of 1967	$	51.43	200,000	200,000	10.0			10.0
$3.24	Series G of 1968	$	51.84	300,000	300,000	15.0			15.0
6.56%	Series of 1968	$	51.44	200,000	200,000	10.0			10.0
Total CL&P				2,324,000	2,324,000	$	116.2		$	116.2
NSTAR Electric
4.25%	Series of 1956	$	103.625	180,000	180,000	$	18.0		$	18.0
4.78%	Series of 1958	$	102.80	250,000	250,000	25.0			25.0
Total NSTAR Electric				430,000	430,000	$	43.0		$	43.0
Fair Value Adjustment due to Merger with NSTAR						(3.6		)	(3.6		)
Other
6.00%	Series of 1958	$	100.00	23	23	$	—		$	—
Total Eversource - Noncontrolling Interest - Preferred Stock of Subsidiaries						$	155.6		$	155.6

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SEGMENT INFORMATION (Tables)

12 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

Summary of Segment Information and Segmented Total Assets

Eversource's segment information is as follows:

	For the Year Ended December 31, 2019
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues	$	6,976.5		$	1,062.2		$	1,389.0		$	214.6		$	1,028.5		$	(2,144.3	)	$	8,526.5
Depreciation and Amortization	(651.3		)	(68.3		)	(253.3		)	(46.9		)	(63.2		)	2.3			(1,080.7		)
Impairment of Northern Pass Transmission	—			—			(239.6		)	—			—			—			(239.6		)
Other Operating Expenses	(5,525.1		)	(830.8		)	(411.2		)	(101.0		)	(891.3		)	2,143.7			(5,615.7		)
Operating Income	800.1			163.1			484.9			66.7			74.0			1.7			1,590.5
Interest Expense	(206.4		)	(47.4		)	(125.7		)	(34.6		)	(170.3		)	51.2			(533.2		)
Interest Income	13.3			0.1			1.5			—			48.7			(50.8		)	12.8
Other Income, Net	46.8			1.6			29.2			0.4			1,041.5			(999.5		)	120.0
Income Tax (Expense)/Benefit	(135.9		)	(21.2		)	(130.5		)	2.4			11.7			—			(273.5		)
Net Income	517.9			96.2			259.4			34.9			1,005.6			(997.4		)	916.6
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income Attributable to Common Shareholders	$	513.3		$	96.2		$	256.5		$	34.9		$	1,005.6		$	(997.4	)	$	909.1
Total Assets (as of)	$	22,541.9		$	4,345.5		$	10,904.0		$	2,351.7		$	20,469.6		$	(19,488.8	)	$	41,123.9
Cash Flows Used for Investments in Plant	$	1,104.2		$	460.2		$	987.0		$	118.0		$	242.1		$	—		$	2,911.5

	For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues (1)	$	6,957.2		$	1,022.2		$	1,286.3		$	212.0		$	936.3		$	(1,965.8	)	$	8,448.2
Depreciation and Amortization	(671.8		)	(75.0		)	(231.8		)	(46.5		)	(49.1		)	2.2			(1,072.0		)
Other Operating Expenses (1)	(5,548.6		)	(787.6		)	(375.5		)	(99.8		)	(831.5		)	1,966.7			(5,676.3		)
Operating Income	736.8			159.6			679.0			65.7			55.7			3.1			1,699.9
Interest Expense	(202.8		)	(44.1		)	(120.6		)	(34.3		)	(129.3		)	32.3			(498.8		)
Interest Income	18.7			—			2.4			—			30.3			(33.3		)	18.1
Other Income/(Loss), Net	67.5			7.1			31.1			(0.4		)	1,185.3			(1,180.3		)	110.3
Income Tax (Expense)/Benefit	(160.2		)	(29.4		)	(161.8		)	(0.1		)	62.5			—			(289.0		)
Net Income	460.0			93.2			430.1			30.9			1,204.5			(1,178.2		)	1,040.5
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income Attributable to Common Shareholders	$	455.4		$	93.2		$	427.2		$	30.9		$	1,204.5		$	(1,178.2	)	$	1,033.0
Total Assets (as of)	$	21,389.1		$	3,904.9		$	10,285.0		$	2,253.0		$	17,874.2		$	(17,464.9	)	$	38,241.3
Cash Flows Used for Investments in Plant (2)	$	961.3		$	351.5		$	976.2		$	102.3		$	178.6		$	—		$	2,569.9

	For the Year Ended December 31, 2017
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues (1)	$	5,542.9		$	947.3		$	1,301.7		$	15.9		$	931.0		$	(986.8	)	$	7,752.0
Depreciation and Amortization	(542.6		)	(72.9		)	(209.4		)	(3.7		)	(37.4		)	2.2			(863.8		)
Other Operating Expenses (1)	(4,072.6		)	(716.4		)	(382.8		)	(8.3		)	(806.6		)	986.7			(5,000.0		)
Operating Income	927.7			158.0			709.5			3.9			87.0			2.1			1,888.2
Interest Expense	(186.3		)	(43.1		)	(115.1		)	(3.1		)	(90.0		)	15.8			(421.8		)
Interest Income	7.3			0.1			1.8			0.1			15.7			(16.7		)	8.3
Other Income, Net	41.6			3.8			27.3			—			1,113.0			(1,086.0		)	99.7
Income Tax Expense	(288.3		)	(44.2		)	(228.7		)	(2.1		)	(15.5		)	(0.1		)	(578.9		)
Net Income/(Loss)	502.0			74.6			394.8			(1.2		)	1,110.2			(1,084.9		)	995.5
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income/(Loss) Attributable to Common Shareholders	$	497.4		$	74.6		$	391.9		$	(1.2	)	$	1,110.2		$	(1,084.9	)	$	988.0
Cash Flows Used for Investments in Plant	$	1,020.7		$	298.2		$	867.6		$	16.0		$	145.6		$	—		$	2,348.1

⁽¹⁾ Effective January 1, 2018, upon implementation of the new revenue accounting guidance, the electric distribution segment is presented gross and intercompany transmission billings are presented in the eliminations column, as Eversource believes that the electric distribution segment acts as a principal, rather than an agent, in its contracts with retail customers. Retail customers contract directly with the electric distribution utility and do not differentiate between distribution and transmission services. Therefore, the electric distribution segment revenues, which are derived from retail customer billings, are presented gross of the eliminations. Prior to 2018, the electric distribution segment presented intercompany electric transmission billings net, based on indicators of net presentation prior to the new revenue guidance.  See Note 23 "Revenues," to the financial statements regarding accounting for revenues.

⁽²⁾

See Note 1B, "Summary of Significant Accounting Policies - Basis of Presentation," for information regarding the correction of cash investments in plant reported in 2018.

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PREFERRED STOCK NOT SUBJECT TO MANDATORY REDEMPTION - Schedule of Preferred Stock by Class (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Class of Stock [Line Items]
Preferred stock value outstanding	$ 155.6	$ 155.6
CL&P
Class of Stock [Line Items]
Shares outstanding (in shares)	2,324,000	2,324,000
Preferred stock value outstanding	$ 116.2	$ 116.2
CL&P | Series of 1947 Preferred Stock at $1.90
Class of Stock [Line Items]
Preferred stock, dividend rate, per-dollar-amount (in dollars per share)	$ 1.90	$ 1.90
Redemption Price Per Share (in dollars per share)	$ 52.50
Shares outstanding (in shares)	163,912	163,912
Preferred stock value outstanding	$ 8.2	$ 8.2
CL&P | Series of 1947 Preferred Stock at $2.00
Class of Stock [Line Items]
Preferred stock, dividend rate, per-dollar-amount (in dollars per share)	$ 2.00	$ 2.00
Redemption Price Per Share (in dollars per share)	$ 54.00
Shares outstanding (in shares)	336,088	336,088
Preferred stock value outstanding	$ 16.8	$ 16.8
CL&P | Series of 1949 Preferred Stock at $2.04
Class of Stock [Line Items]
Preferred stock, dividend rate, per-dollar-amount (in dollars per share)	$ 2.04	$ 2.04
Redemption Price Per Share (in dollars per share)	$ 52.00
Shares outstanding (in shares)	100,000	100,000
Preferred stock value outstanding	$ 5.0	$ 5.0
CL&P | Series of 1949 Preferred Stock at $2.20
Class of Stock [Line Items]
Preferred stock, dividend rate, per-dollar-amount (in dollars per share)	$ 2.20	$ 2.20
Redemption Price Per Share (in dollars per share)	$ 52.50
Shares outstanding (in shares)	200,000	200,000
Preferred stock value outstanding	$ 10.0	$ 10.0
CL&P | Series of 1949 Preferred Stock at 3.90%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	3.90%	3.90%
Redemption Price Per Share (in dollars per share)	$ 50.50
Shares outstanding (in shares)	160,000	160,000
Preferred stock value outstanding	$ 8.0	$ 8.0
CL&P | Series E of 1954 Preferred Stock at $2.06
Class of Stock [Line Items]
Preferred stock, dividend rate, per-dollar-amount (in dollars per share)	$ 2.06	$ 2.06
Redemption Price Per Share (in dollars per share)	$ 51.00
Shares outstanding (in shares)	200,000	200,000
Preferred stock value outstanding	$ 10.0	$ 10.0
CL&P | Series F of 1955 Preferred Stock at $2.09
Class of Stock [Line Items]
Preferred stock, dividend rate, per-dollar-amount (in dollars per share)	$ 2.09	$ 2.09
Redemption Price Per Share (in dollars per share)	$ 51.00
Shares outstanding (in shares)	100,000	100,000
Preferred stock value outstanding	$ 5.0	$ 5.0
CL&P | Series of 1956 Preferred Stock at 4.5%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	4.50%	4.50%
Redemption Price Per Share (in dollars per share)	$ 50.75
Shares outstanding (in shares)	104,000	104,000
Preferred stock value outstanding	$ 5.2	$ 5.2
CL&P | Series of 1958 Preferred Stock at 4.96%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	4.96%	4.96%
Redemption Price Per Share (in dollars per share)	$ 50.50
Shares outstanding (in shares)	100,000	100,000
Preferred stock value outstanding	$ 5.0	$ 5.0
CL&P | Series of 1963 Preferred Stock at 4.5%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	4.50%	4.50%
Redemption Price Per Share (in dollars per share)	$ 50.50
Shares outstanding (in shares)	160,000	160,000
Preferred stock value outstanding	$ 8.0	$ 8.0
CL&P | Series of 1967 Preferred Stock at 5.28%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	5.28%	5.28%
Redemption Price Per Share (in dollars per share)	$ 51.43
Shares outstanding (in shares)	200,000	200,000
Preferred stock value outstanding	$ 10.0	$ 10.0
CL&P | Series G of 1968 Preferred Stock at $3.24
Class of Stock [Line Items]
Preferred stock, dividend rate, per-dollar-amount (in dollars per share)	$ 3.24	$ 3.24
Redemption Price Per Share (in dollars per share)	$ 51.84
Shares outstanding (in shares)	300,000	300,000
Preferred stock value outstanding	$ 15.0	$ 15.0
CL&P | Series of 1968 Preferred Stock at 6.56%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	6.56%	6.56%
Redemption Price Per Share (in dollars per share)	$ 51.44
Shares outstanding (in shares)	200,000	200,000
Preferred stock value outstanding	$ 10.0	$ 10.0
NSTAR Electric
Class of Stock [Line Items]
Shares outstanding (in shares)	430,000	430,000
Preferred stock value outstanding	$ 43.0	$ 43.0
NSTAR Electric | Preferred Stock 4.25%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	4.25%	4.25%
Redemption Price Per Share (in dollars per share)	$ 103.625
Shares outstanding (in shares)	180,000	180,000
Preferred stock value outstanding	$ 18.0	$ 18.0
NSTAR Electric | Preferred Stock 4.78%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	4.78%	4.78%
Redemption Price Per Share (in dollars per share)	$ 102.80
Shares outstanding (in shares)	250,000	250,000
Preferred stock value outstanding	$ 25.0	$ 25.0
Aquarion Water Company | Series of Preferred Stock at 6%
Class of Stock [Line Items]
Preferred stock, dividend rate (as a percentage)	6.00%	6.00%
Redemption Price Per Share (in dollars per share)	$ 100.00
Shares outstanding (in shares)	23	23
Preferred stock value outstanding	$ 0.0	$ 0.0
Fair Value Adjustment | NSTAR Electric
Class of Stock [Line Items]
Preferred stock value outstanding	$ 3.6	$ 3.6

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

The consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries. Intercompany transactions have been eliminated in consolidation.  The accompanying consolidated financial statements of Eversource, NSTAR Electric and PSNH and the financial statements of CL&P are herein collectively referred to as the "financial statements."  

The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent liabilities as of 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.

Eversource consolidates the operations of CYAPC and YAEC, both of which are inactive regional nuclear generation companies engaged in the long-term storage of their spent nuclear fuel. Eversource consolidates CYAPC and YAEC because CL&P's, NSTAR Electric's and PSNH's combined ownership and voting interests in each of these entities is greater than 50 percent.  Intercompany transactions between CL&P, NSTAR Electric, PSNH and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.  

Eversource's consolidated financial information includes the results of Aquarion and its subsidiaries beginning from the date of the acquisition on December 4, 2017.

Eversource holds several equity ownership interests that are not consolidated and are accounted for under the equity method.

In accordance with accounting guidance on noncontrolling interests in consolidated financial statements, the Preferred Stock of CL&P and the Preferred Stock of NSTAR Electric, which are not owned by Eversource or its consolidated subsidiaries and are not subject to mandatory redemption, have been presented as noncontrolling interests in the financial statements of Eversource.  The Preferred Stock of CL&P and the Preferred Stock of NSTAR Electric are considered to be temporary equity and have been classified between liabilities and permanent shareholders' equity on the balance sheets of Eversource, CL&P and NSTAR Electric due to a provision in the preferred stock agreements of both CL&P and NSTAR Electric that grant preferred stockholders the right to elect a majority of the CL&P and NSTAR Electric Boards of Directors, respectively, should certain conditions exist, such as if preferred dividends are in arrears for a specified amount of time.  The Net Income reported in the statements of income and cash flows represents net income prior to apportionment to noncontrolling interests, which is represented by dividends on preferred stock of CL&P and NSTAR Electric.

Eversource's utility subsidiaries' electric, natural gas and water distribution and transmission businesses are subject to rate-regulation that is based on cost recovery and meets the criteria for application of accounting guidance for entities with rate-regulated operations, which considers the effect of regulation on the differences in the timing of the recognition of certain revenues and expenses from those of other businesses and industries.  See Note 2, "Regulatory Accounting," for further information.

Certain reclassifications of prior year data were made in the accompanying financial statements to conform to the current year presentation.

The Eversource and PSNH 2018 statements of cash flows, the 2018 supplemental cash flow information footnote, and the 2018 segment footnote were revised to correct an error in the presentation of non-cash capital additions.  The impact of this revision on the statement of cash flows is an increase to operating cash inflows in Accounts Payable of $46.6 million and a corresponding increase to investing cash outflows in Investments in Property, Plant and Equipment for the year ended December 31, 2018.  This revision is not deemed material, individually or in the aggregate, to the previously issued financial statements.

Accounting Standards

Accounting Standards

Accounting Standards Issued but Not Yet Effective: In June 2016, the FASB issued Accounting Standards Update (“ASU”) 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. Under the new guidance, immediate recognition of credit losses expected over the life of a financial instrument is required. The standard is effective January 1, 2020. The Company assessed the impacts of this standard on the accounting for credit losses on its financial instruments, including accounts receivable, and does not expect a material impact on the financial statements of Eversource, CL&P, NSTAR Electric or PSNH.

In December 2019, the FASB issued ASU 2019-12, Income Taxes (Topic 740) - Simplifying the Accounting for Income Taxes, which eliminates certain exceptions to the general principles of current income tax guidance in ASC 740, Income Taxes, and simplifies and improves consistency in application of that income tax guidance through clarifications of, and amendments to, ASC 740. The guidance is effective in the first quarter of 2021.  The Company is evaluating the impact of this standard on the financial statements of Eversource, CL&P, NSTAR Electric and PSNH.

Accounting Standards Recently Adopted: On January 1, 2019, the Company adopted ASU 2016-02, Leases (Topic 842), which amended existing lease accounting guidance. The Company applied the Topic 842 lease criteria to new leases and lease renewals entered into effective on or after January 1, 2019.  The ASU required balance sheet recognition of leases deemed to be operating leases as well as additional disclosure requirements.  The recognition, measurement and presentation of expenses and cash flows were not significantly changed.

The Company utilized the modified retrospective transition method allowed in ASU 2018-11, Leases (Topic 842) - Targeted Improvements, which allowed the Company to adopt the new leases standard as of January 1, 2019, with prior periods presented in the financial statements continuing to follow existing lease accounting guidance under Topic 840 (Leases) in the accounting literature.  Implementation of ASU 2018-11 had no effect on retained earnings, and the requirements of the new lease standard (Topic 842) are reflected in the 2019 financial statements and footnotes.

The Company elected the practical expedient package whereby it did not need to reassess whether or not an existing contract is or contains a lease or whether a lease is an operating or capital lease, and it did not need to reassess initial direct costs for leases. Election of this practical expedient allowed us to carry forward our historical lease classifications. The Company elected the practical expedient to not reevaluate land easements existing at adoption if they were not previously accounted for as leases. The Company also elected to use the discount rate as of the January 1, 2019 implementation date to discount its operating lease liabilities. The Company did not elect the hindsight practical expedient to determine the lease term for existing leases.

The Company determined the impact the ASUs had on its financial statements by reviewing its lease population and identifying lease data needed for the disclosure requirements. The Company implemented a new lease accounting system in 2019 to ensure ongoing compliance with the ASU’s requirements. Adoption of the new standard resulted in the recording of operating lease liabilities and right-of-use assets on the balance sheet upon transition at January 1, 2019 of $58.0 million at Eversource, $25.3 million at NSTAR Electric, $0.6 million at CL&P, and $0.6 million at PSNH. Implementation of the new guidance did not have an impact on each company’s results of operations or cash flows.

Cash

Cash

Cash includes cash on hand.  At the end of each reporting period, any overdraft amounts are reclassified from Cash to Accounts Payable on the balance sheets.

Provision for Uncollectible Accounts

Provision for Uncollectible Accounts

Eversource, including CL&P, NSTAR Electric and PSNH, presents its receivables at estimated net realizable value by maintaining a provision for uncollectible accounts.  This provision is determined based upon a variety of judgments and factors, including the application of an estimated uncollectible percentage to each receivable aging category.  The estimate is based upon historical collection and write-off experience and management's assessment of collectability from customers.  Management continuously assesses the collectability of receivables and adjusts collectability estimates based on actual experience.  Receivable balances are written off against the provision for uncollectible accounts when the customer accounts are terminated and these balances are deemed to be uncollectible.

The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively.  The DPU allows NSTAR Electric and NSTAR Gas to recover in rates, amounts associated with certain uncollectible hardship accounts receivable.  These uncollectible hardship customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets.  

Transfer of Energy Efficiency Loans

Transfer of Energy Efficiency LoansIn 2018, CL&P transferred $41.3 million of its energy efficiency customer loan portfolio to two outside lenders in order to make additional loans to customers.  CL&P remains the servicer of the loans and will transmit customer payments to the lenders.  Under a three-year agreement with the lenders, additional energy efficiency loans will also be transferred with a maximum amount outstanding under this program of $55 million.  The transaction did not qualify as a sale for accounting purposes, and the amounts of the loans are included in Accounts Receivable, Net and Other Long-Term Assets, and are offset by Other Current Liabilities and Other Long-Term Liabilities on CL&P’s balance sheet.

Fuel, Materials, Supplies and REC Inventory

Fuel, Materials, Supplies and REC InventoryFuel, Materials, Supplies and REC Inventory include natural gas inventory, materials and supplies purchased primarily for construction or operation and maintenance purposes, and RECs.  Inventory is valued at the lower of cost or net realizable value. RECs are purchased from suppliers of renewable sources of generation and are used to meet state mandated Renewable Portfolio Standards requirements.  

Fair Value Measurements

Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" (normal) and to the marketable securities held in trusts.  Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill, long-lived assets and AROs. We also applied this guidance in the valuation of our basis differences in our equity method offshore wind investments (see Note 6, "Investments in Unconsolidated Affiliates," for further information). The fair value measurement guidance was also applied in estimating the fair value of preferred stock, long-term debt and RRBs.

Fair Value Hierarchy:  In measuring fair value, Eversource uses observable market data when available in order to minimize the use of unobservable inputs.  Inputs used in fair value measurements are categorized into three fair value hierarchy levels for disclosure purposes.  The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement.  Eversource evaluates the classification of assets and liabilities measured at fair value on a quarterly basis, and Eversource's policy is to recognize transfers between levels of the fair value hierarchy as of the end of the reporting period.  The three levels of the fair value hierarchy are described below:

Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  

Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable.

Level 3 - Quoted market prices are not available.  Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable.  Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products.  

Uncategorized - Investments that are measured at net asset value are not categorized within the fair value hierarchy.

Derivative Accounting

Derivative Accounting

Many of the electric and natural gas companies' contracts for the purchase and sale of energy or energy-related products are derivatives.  The accounting treatment for energy contracts entered into varies and depends on the intended use of the particular contract and on whether or not the contract is a derivative.  

The application of derivative accounting is complex and requires management judgment in the following respects: identification of derivatives and embedded derivatives, election and designation of a contract as normal, and determination of the fair value of derivative contracts.  All of these judgments can have a significant impact on the financial statements.  The judgment applied in the election of a contract as normal (and resulting accrual accounting) includes the conclusion that it is probable at the inception of the contract and throughout its term that it will result in physical delivery of the underlying product and that the quantities will be used or sold by the business in the normal course of business.  If facts and circumstances change and management can no longer support this conclusion, then a contract cannot be considered normal, accrual accounting is terminated, and fair value accounting is applied prospectively.  

The fair value of derivative contracts is based upon the contract terms and conditions and the underlying market price or fair value per unit.  When quantities are not specified in the contract, the Company determines whether the contract has a determinable quantity by using amounts referenced in default provisions and other relevant sections of the contract.  The fair value of derivative assets and liabilities with the same counterparty are offset and recorded as a net derivative asset or liability on the balance sheets.  

Regulatory assets or regulatory liabilities are recorded to offset the fair values of derivative contracts related to energy and energy-related products, as contract settlements are recovered from, or refunded to, customers in future rates. All changes in the fair value of derivative contracts are recorded as regulatory assets or liabilities and do not impact net income.

Allowance for Funds Used During Construction

Allowance for Funds Used During Construction

AFUDC represents the cost of borrowed and equity funds used to finance construction and is included in the cost of the electric, natural gas and water companies' utility plant on the balance sheet.  The portion of AFUDC attributable to borrowed funds is recorded as a reduction of Interest Expense, and the AFUDC related to equity funds is recorded as Other Income, Net on the statements of income.  AFUDC costs are recovered from customers over the service life of the related plant in the form of increased revenue collected as a result of higher depreciation expense.

The average AFUDC rate is based on a FERC-prescribed formula using the cost of a company's short-term financings and capitalization (preferred stock, long-term debt and common equity), as appropriate.  The average rate is applied to average eligible CWIP amounts to calculate AFUDC.

Other Taxes

Other TaxesEversource's companies that serve customers in Connecticut collect gross receipts taxes levied by the state of Connecticut from their customers.

As agents for state and local governments, Eversource's companies that serve customers in Connecticut and Massachusetts collect certain sales taxes that are recorded on a net basis with no impact on the statements of income.  

Separate from above were amounts recorded as Taxes Other Than Income Taxes related to the remittance to the State of Connecticut of energy efficiency funds collected from customers in Operating Revenues. These amounts were $21.4 million and $46.8 million in 2019 and 2018, respectively. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. These amounts were recorded separately, with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the Eversource and CL&P statements of income.

Related Parties

Related Parties

Eversource Service, Eversource's service company, provides centralized accounting, administrative, engineering, financial, information technology, legal, operational, planning, purchasing, tax, and other services to Eversource's companies.  The Rocky River Realty Company, Renewable Properties, Inc. and Properties, Inc., three other Eversource subsidiaries, construct, acquire or lease some of the property and facilities used by Eversource's companies.

As of both December 31, 2019 and 2018, CL&P, NSTAR Electric and PSNH had long-term receivables from Eversource Service in the amounts of $25.0 million, $5.5 million and $3.8 million, respectively, which were included in Other Long-Term Assets on the balance sheets. These amounts related to the funding of investments held in trust by Eversource Service in connection with certain postretirement benefits for CL&P, NSTAR Electric and PSNH employees and have been eliminated in consolidation on the Eversource financial statements.  

Included in the CL&P, NSTAR Electric and PSNH balance sheets as of December 31, 2019 and 2018 were Accounts Receivable from Affiliated Companies and Accounts Payable to Affiliated Companies relating to transactions between CL&P, NSTAR Electric and PSNH and other subsidiaries that are wholly-owned by Eversource.  These amounts have been eliminated in consolidation on the Eversource financial statements.

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CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Current Assets:
Cash	$ 15,432	$ 108,068
Receivables, Net	989,383	994,055
Unbilled Revenues	181,006	176,285
Fuel, Materials, Supplies and REC Inventory	235,471	238,042
Regulatory Assets	651,112	514,779
Prepayments and Other Current Assets	342,135	260,995
Total Current Assets	2,414,539	2,292,224
Property, Plant and Equipment, Net	27,585,470	25,610,428
Deferred Debits and Other Assets:
Regulatory Assets	4,863,639	4,631,137
Goodwill	4,427,266	4,427,266
Investments in Unconsolidated Affiliates	871,633	464,286
Marketable Securities	449,130	417,508
Other Long-Term Assets	512,238	398,407
Total Deferred Debits and Other Assets	11,123,906	10,338,604
Total Assets	41,123,915	38,241,256
Current Liabilities:
Notes Payable	889,084	910,000
Long-Term Debt – Current Portion	327,411	837,319
Rate Reduction Bonds – Current Portion	43,210	52,332
Accounts Payable	1,147,872	1,119,995
Regulatory Liabilities	361,152	370,230
Other Current Liabilities	836,834	823,006
Total Current Liabilities	3,605,563	4,112,882
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	3,755,777	3,506,030
Regulatory Liabilities	3,658,042	3,609,475
Derivative Liabilities	338,710	379,562
Asset Retirement Obligations	488,511	466,236
Accrued Pension, SERP and PBOP	1,370,245	962,510
Other Long-Term Liabilities	810,553	730,100
Total Deferred Credits and Other Liabilities	10,421,838	9,653,913
Capitalization:
Long-Term Debt	13,770,828	12,248,743
Rate Reduction Bonds	540,122	583,331
Noncontrolling Interest - Preferred Stock of Subsidiaries	155,570	155,570
Common Shareholders' Equity:
Common Shares	1,729,292	1,669,392
Capital Surplus, Paid In	7,087,768	6,241,222
Retained Earnings	4,177,048	3,953,974
Accumulated Other Comprehensive Income (Loss)	(65,059)	(60,000)
Treasury Stock	(299,055)	(317,771)
Common Shareholders' Equity	12,629,994	11,486,817
Commitments and Contingencies (Note 13)
Total Liabilities and Capitalization	41,123,915	38,241,256
The Connecticut Light and Power Company
Current Assets:
Cash	0	87,721
Receivables, Net	400,927	397,026
Accounts Receivable from Affiliated Companies	24,577	23,082
Unbilled Revenues	56,465	56,971
Fuel, Materials, Supplies and REC Inventory	50,700	44,529
Regulatory Assets	178,607	125,155
Prepayments and Other Current Assets	73,184	60,279
Total Current Assets	784,460	794,763
Property, Plant and Equipment, Net	9,625,765	8,909,701
Deferred Debits and Other Assets:
Regulatory Assets	1,557,261	1,505,488
Other Long-Term Assets	217,705	199,767
Total Deferred Debits and Other Assets	1,774,966	1,705,255
Total Assets	12,185,191	11,409,719
Current Liabilities:
Notes Payable to Eversource Parent	63,800	0
Long-Term Debt – Current Portion	0	250,000
Accounts Payable	374,698	324,983
Accounts Payable to Affiliated Companies	97,793	26,452
Obligations to Third Party Suppliers	56,952	56,248
Regulatory Liabilities	82,763	109,614
Derivative Liabilities	67,804	55,058
Other Current Liabilities	132,339	161,088
Total Current Liabilities	876,149	983,443
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,244,551	1,166,784
Regulatory Liabilities	1,164,991	1,122,157
Derivative Liabilities	338,594	379,536
Accrued Pension, SERP and PBOP	391,159	282,771
Other Long-Term Liabilities	147,586	155,495
Total Deferred Credits and Other Liabilities	3,286,881	3,106,743
Capitalization:
Long-Term Debt	3,518,136	3,004,016
Noncontrolling Interest - Preferred Stock of Subsidiaries	116,200	116,200
Common Shareholders' Equity:
Common Shares	60,352	60,352
Capital Surplus, Paid In	2,535,765	2,410,765
Retained Earnings	1,791,392	1,727,899
Accumulated Other Comprehensive Income (Loss)	316	301
Common Shareholders' Equity	4,387,825	4,199,317
Commitments and Contingencies (Note 13)
Total Liabilities and Capitalization	12,185,191	11,409,719
NSTAR Electric Company
Current Assets:
Cash	52	1,606
Receivables, Net	346,785	361,296
Accounts Receivable from Affiliated Companies	29,914	31,344
Unbilled Revenues	37,482	34,518
Fuel, Materials, Supplies and REC Inventory	124,060	114,202
Regulatory Assets	285,591	241,747
Prepayments and Other Current Assets	31,150	51,960
Total Current Assets	855,034	836,673
Property, Plant and Equipment, Net	9,472,770	8,794,700
Deferred Debits and Other Assets:
Regulatory Assets	1,250,029	1,196,512
Prepaid PBOP	166,058	132,810
Other Long-Term Assets	144,368	109,764
Total Deferred Debits and Other Assets	1,560,455	1,439,086
Total Assets	11,888,259	11,070,459
Current Liabilities:
Notes Payable	10,500	278,500
Notes Payable to Eversource Parent	30,300	0
Long-Term Debt – Current Portion	95,000	0
Accounts Payable	363,691	384,398
Accounts Payable to Affiliated Companies	96,307	89,636
Obligations to Third Party Suppliers	108,827	109,547
Renewable Portfolio Standards Compliance Obligations	150,429	139,898
Regulatory Liabilities	209,180	190,620
Other Current Liabilities	71,333	74,872
Total Current Liabilities	1,135,567	1,267,471
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,357,265	1,294,467
Regulatory Liabilities	1,516,585	1,513,279
Accrued Pension, SERP and PBOP	108,243	14,145
Other Long-Term Liabilities	320,629	263,096
Total Deferred Credits and Other Liabilities	3,302,722	3,084,987
Capitalization:
Long-Term Debt	3,247,086	2,944,846
Noncontrolling Interest - Preferred Stock of Subsidiaries	43,000	43,000
Common Shareholders' Equity:
Common Shares	0	0
Capital Surplus, Paid In	1,813,442	1,633,442
Retained Earnings	2,346,287	2,098,091
Accumulated Other Comprehensive Income (Loss)	155	(1,378)
Common Shareholders' Equity	4,159,884	3,730,155
Commitments and Contingencies (Note 13)
Total Liabilities and Capitalization	11,888,259	11,070,459
Public Service Company of New Hampshire
Current Assets:
Cash	413	1,439
Receivables, Net	99,934	104,854
Accounts Receivable from Affiliated Companies	6,763	8,444
Unbilled Revenues	48,146	47,145
Taxes Receivable	1,497	25,913
Fuel, Materials, Supplies and REC Inventory	24,957	37,504
Regulatory Assets	84,053	67,228
Special Deposits	32,513	47,498
Prepayments and Other Current Assets	17,934	17,564
Total Current Assets	316,210	357,589
Property, Plant and Equipment, Net	3,129,506	2,880,073
Deferred Debits and Other Assets:
Regulatory Assets	861,672	862,288
Other Long-Term Assets	43,270	27,406
Total Deferred Debits and Other Assets	904,942	889,694
Total Assets	4,350,658	4,127,356
Current Liabilities:
Notes Payable to Eversource Parent	27,000	57,000
Long-Term Debt – Current Portion	0	150,000
Rate Reduction Bonds – Current Portion	43,210	52,332
Accounts Payable	127,081	111,292
Accounts Payable to Affiliated Companies	37,946	26,029
Regulatory Liabilities	65,766	55,526
Accrued Interest	19,138	19,953
Other Current Liabilities	32,736	44,093
Total Current Liabilities	352,877	516,225
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	506,212	481,221
Regulatory Liabilities	413,381	428,069
Accrued Pension, SERP and PBOP	157,638	124,457
Other Long-Term Liabilities	37,075	36,339
Total Deferred Credits and Other Liabilities	1,114,306	1,070,086
Capitalization:
Long-Term Debt	951,620	655,173
Rate Reduction Bonds	540,122	583,331
Common Shareholders' Equity:
Common Shares	0	0
Capital Surplus, Paid In	903,134	678,134
Retained Earnings	490,306	627,258
Accumulated Other Comprehensive Income (Loss)	(1,707)	(2,851)
Common Shareholders' Equity	1,391,733	1,302,541
Commitments and Contingencies (Note 13)
Total Liabilities and Capitalization	$ 4,350,658	$ 4,127,356

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COMMITMENTS AND CONTINGENCIES - Guarantees and Obligations Narrative (Details)	Dec. 31, 2019 USD ($)
Guarantee Of Financial Obligations Of Npt
Loss Contingencies [Line Items]
Maximum exposure	$ 25,000,000

XML

COMMITMENTS AND CONTINGENCIES - Schedule of Estimated Future Annual Costs of Long term Contractual Agreement (Details) $ in Millions	Dec. 31, 2019 USD ($)
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	$ 998.8
2021	941.6
2022	946.5
2023	897.5
2024	881.9
Thereafter	4,785.2
Total	9,451.5
Renewable Energy
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	614.6
2021	594.3
2022	651.7
2023	629.1
2024	624.8
Thereafter	3,590.6
Total	6,705.1
Purchased Power and Capacity
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	73.5
2021	69.0
2022	75.1
2023	81.6
2024	75.9
Thereafter	71.5
Total	446.6
Peaker CfDs
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	22.4
2021	23.0
2022	16.9
2023	20.1
2024	15.5
Thereafter	29.8
Total	127.7
Natural Gas Procurement
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	266.2
2021	255.3
2022	202.8
2023	166.7
2024	165.7
Thereafter	1,093.3
Total	2,150.0
Transmission Support Commitments
Recorded Unconditional Purchase Obligation, Fiscal Year Maturity Schedule [Abstract]
2020	22.1
2021	0.0
2022	0.0
2023	0.0
2024	0.0
Thereafter	0.0
Total	22.1
CL&P
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	558.2
2021	547.9
2022	602.7
2023	614.3
2024	605.8
Thereafter	2,875.9
Total	5,804.8
CL&P | Renewable Energy
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	457.3
2021	459.6
2022	514.4
2023	516.2
2024	517.4
Thereafter	2,790.6
Total	5,255.5
CL&P | Purchased Power and Capacity
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	69.8
2021	65.3
2022	71.4
2023	78.0
2024	72.9
Thereafter	55.5
Total	412.9
CL&P | Peaker CfDs
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	22.4
2021	23.0
2022	16.9
2023	20.1
2024	15.5
Thereafter	29.8
Total	127.7
CL&P | Transmission Support Commitments
Recorded Unconditional Purchase Obligation, Fiscal Year Maturity Schedule [Abstract]
2020	8.7
2021	0.0
2022	0.0
2023	0.0
2024	0.0
Thereafter	0.0
Total	8.7
NSTAR Electric
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	107.3
2021	94.3
2022	94.5
2023	69.6
2024	66.8
Thereafter	434.1
Total	866.6
NSTAR Electric | Renewable Energy
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	95.5
2021	91.2
2022	91.4
2023	66.6
2024	63.8
Thereafter	418.1
Total	826.6
NSTAR Electric | Purchased Power and Capacity
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	3.1
2021	3.1
2022	3.1
2023	3.0
2024	3.0
Thereafter	16.0
Total	31.3
NSTAR Electric | Transmission Support Commitments
Recorded Unconditional Purchase Obligation, Fiscal Year Maturity Schedule [Abstract]
2020	8.7
2021	0.0
2022	0.0
2023	0.0
2024	0.0
Thereafter	0.0
Total	8.7
PSNH
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	67.1
2021	44.1
2022	46.5
2023	46.9
2024	43.6
Thereafter	381.9
Total	630.1
PSNH | Renewable Energy
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	61.8
2021	43.5
2022	45.9
2023	46.3
2024	43.6
Thereafter	381.9
Total	623.0
PSNH | Purchased Power and Capacity
Unrecorded Unconditional Purchase Obligation, Fiscal Year Maturity [Abstract]
2020	0.6
2021	0.6
2022	0.6
2023	0.6
2024	0.0
Thereafter	0.0
Total	2.4
PSNH | Transmission Support Commitments
Recorded Unconditional Purchase Obligation, Fiscal Year Maturity Schedule [Abstract]
2020	4.7
2021	0.0
2022	0.0
2023	0.0
2024	0.0
Thereafter	0.0
Total	$ 4.7

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ACQUISITION OF AQUARION AND GOODWILL

12 Months Ended

Dec. 31, 2019

Business Combinations [Abstract]

ACQUISITION OF AQUARION AND GOODWILL

ACQUISITION OF AQUARION AND GOODWILL

A.    Acquisition of Aquarion

On December 4, 2017, Eversource acquired Aquarion for a purchase price of $1.675 billion, consisting of approximately $880 million in cash and $795 million of assumed Aquarion debt. Aquarion is a holding company that owns three separate regulated water utility subsidiaries engaged in the water collection, treatment and distribution business that operate in Connecticut, Massachusetts and New Hampshire. These regulated utilities collect, treat and distribute water to residential, commercial and industrial customers, to other utilities for resale, and for private and municipal fire protection. Aquarion and its subsidiaries became wholly-owned subsidiaries of Eversource, and Eversource's consolidated financial information includes Aquarion and its subsidiaries' activity beginning December 4, 2017. The approximate $880 million cash purchase price included the $745 million equity purchase price plus a $135 million shareholder loan that was repaid at closing.

Pro Forma Financial Information: The following unaudited pro forma financial information reflects the pro forma combined results of operations of Eversource and Aquarion and reflects the amortization of purchase price adjustments assuming the acquisition had taken place on January 1, 2017. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of Eversource.

(Pro forma amounts in millions, except share amounts)	For the Year Ended December 31, 2017
Operating Revenues	$	7,947.7
Net Income Attributable to Common Shareholders	1,019.1
Basic EPS	3.21
Diluted EPS	3.20

Aquarion Revenues and Pre-Tax Income: The impact of Aquarion on Eversource's accompanying consolidated statement of income included operating revenues of $15.9 million and pre-tax income of $1.1 million for the year ended December 31, 2017.

B.    Goodwill

In a business combination, the excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed

is recognized as goodwill. Goodwill is evaluated for impairment at least annually and more frequently if indicators of impairment arise. In accordance with the accounting standards, if the fair value of a reporting unit is less than its carrying value (including goodwill), the goodwill is tested for impairment. Goodwill is not subject to amortization, however is subject to a fair value based assessment for impairment at least annually and whenever facts or circumstances indicate that there may be an impairment.  A resulting write-down, if any, would be charged to Operating Expenses.   

Eversource's reporting units for the purpose of testing goodwill are Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution. These reporting units are consistent with the operating segments underlying the reportable segments identified in Note 24, "Segment Information," to the financial statements.

Eversource completed its annual goodwill impairment test for Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reporting units as of October 1, 2019 and determined that no impairment existed. There were no events subsequent to October 1, 2019 that indicated impairment of goodwill. The annual goodwill assessment included an evaluation of the Company's share price and credit ratings, analyst reports, financial performance, cost and risk factors, long-term strategy, growth and future projections, as well as macroeconomic, industry and market conditions.  This evaluation required the consideration of several factors that impact the fair value of the reporting units, including conditions and assumptions that affect the future cash flows of the reporting units. Key considerations include discount rates, utility sector market performance and merger transaction multiples, and internal estimates of future cash flows and net income.  

 The following table presents goodwill by reportable segment as of December 31, 2019 and 2018:

(Billions of Dollars)	Electric Distribution		Electric Transmission		Natural Gas Distribution		Water Distribution		Total
Goodwill	$	2.5	$	0.6	$	0.4	$	0.9	$	4.4

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CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Statement of Stockholders' Equity [Abstract]
Dividends on common shares (in dollars per share)	$ 2.14	$ 2.02	$ 1.90
Per share par value (in dollars per share)	$ 5	$ 5

XML

DERIVATIVE INSTRUMENTS

12 Months Ended

Dec. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE INSTRUMENTS

DERIVATIVE INSTRUMENTS

The electric and natural gas companies purchase and procure energy and energy-related products, which are subject to price volatility, for their customers.  The costs associated with supplying energy to customers are recoverable from customers in future rates.  These regulated companies manage the risks associated with the price volatility of energy and energy-related products through the use of derivative and non-derivative contracts.  

Many of the derivative contracts meet the definition of, and are designated as, normal and qualify for accrual accounting under the applicable accounting guidance.  The costs and benefits of derivative contracts that meet the definition of normal are recognized in Operating Expenses on the statements of income, as applicable, as electricity or natural gas is delivered.

Derivative contracts that are not designated as normal are recorded at fair value as current or long-term Derivative Assets or Derivative Liabilities on the balance sheets.  For the electric and natural gas companies, regulatory assets or regulatory liabilities are recorded to offset the fair values of derivatives, as contract settlement amounts are recovered from, or refunded to, customers in their respective energy supply rates.  

The gross fair values of derivative assets and liabilities with the same counterparty are offset and reported as net Derivative Assets or Derivative Liabilities, with current and long-term portions, on the balance sheets.  The following table presents the gross fair values of contracts, categorized by risk type, and the net amounts recorded as current or long-term derivative assets or liabilities:

		As of December 31,
		2019									2018
(Millions of Dollars)	Fair Value Hierarchy	Commodity Supply and Price Risk Management			Netting (1)			Net Amount Recorded as a Derivative			Commodity Supply and Price Risk Management			Netting (1)			Net Amount Recorded as a Derivative
Current Derivative Assets:
CL&P	Level 3	$	12.2		$	(0.4	)	$	11.8		$	9.6		$	(3.4	)	$	6.2
Other	Level 2	—			—			—			1.5			(0.9		)	0.6
Long-Term Derivative Assets:
CL&P	Level 3	67.5			(2.1		)	65.4			74.2			(2.3		)	71.9
Current Derivative Liabilities:
CL&P	Level 3	(67.8		)	—			(67.8		)	(55.1		)	—			(55.1		)
Other	Level 2	(5.2		)	—			(5.2		)	—			—			—
Long-Term Derivative Liabilities:
CL&P	Level 3	(338.6		)	—			(338.6		)	(379.5		)	—			(379.5		)
Other	Level 2	(0.1		)	—			(0.1		)	—			—			—

⁽¹⁾ Amounts represent derivative assets and liabilities that Eversource elected to record net on the balance sheets.  These amounts are subject to master netting agreements or similar agreements for which the right of offset exists.

The business activities that result in the recognition of derivative assets also create exposure to various counterparties.  As of December 31, 2019, CL&P's derivative assets were exposed to counterparty credit risk and contracted with investment grade entities.  

For further information on the fair value of derivative contracts, see Note 1I, "Summary of Significant Accounting Policies – Fair Value Measurements," and Note 1J, "Summary of Significant Accounting Policies – Derivative Accounting," to the financial statements.

Derivative Contracts at Fair Value with Offsetting Regulatory Amounts

Commodity Supply and Price Risk Management:  As required by regulation, CL&P, along with UI, has capacity-related contracts with generation facilities.  CL&P has a sharing agreement with UI, with 80 percent of the costs or benefits of each contract borne by or allocated to CL&P and 20 percent borne by or allocated to UI.  The combined capacities of these contracts as of December 31, 2019 and 2018 were 676 MW and 787 MW, respectively.  The capacity contracts extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market price received in the ISO-NE capacity markets.  In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020.

As of December 31, 2019 and 2018, Eversource had New York Mercantile Exchange (NYMEX) financial contracts for natural gas futures in order to reduce variability associated with the price of 9.6 million and 12.5 million MMBtu of natural gas, respectively.

For the years ended December 31, 2019, 2018 and 2017, there were losses of $20.7 million, $25.0 million and $29.0 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource's derivative contracts.

Fair Value Measurements of Derivative Instruments

Derivative contracts classified as Level 2 in the fair value hierarchy relate to the financial contracts for natural gas futures.  Prices are obtained from broker quotes and are based on actual market activity.  The contracts are valued using NYMEX natural gas prices.  Valuations of these contracts also incorporate discount rates using the yield curve approach.  

The fair value of derivative contracts classified as Level 3 utilizes significant unobservable inputs.  The fair value is modeled using income techniques, such as discounted cash flow valuations adjusted for assumptions related to exit price.  Significant observable inputs for valuations of these contracts include energy and energy-related product prices in future years for which quoted prices in an active market exist.  Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy and energy-related products, and accounting requirements.  The future capacity prices for periods that are not quoted in an active market or established at auction are based on available market data and are escalated based on estimates of inflation in order to address the full term of the contract.  

Valuations of derivative contracts using a discounted cash flow methodology include assumptions regarding the timing and likelihood of scheduled payments and also reflect non-performance risk, including credit, using the default probability approach based on the counterparty's credit rating for assets and the Company's credit rating for liabilities.  Valuations incorporate estimates of premiums or discounts that would be required by a market participant to arrive at an exit price, using historical market transactions adjusted for the terms of the contract.  

The following is a summary of Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts:

	As of December 31,
	2019						2018
CL&P	Range					Period Covered	Range					Period Covered
Capacity Prices	$	3.01	—	7.34	per kW-Month	2023 - 2026	$	4.30	—	7.44	per kW-Month	2022 - 2026
Forward Reserve	0.80		—	1.90	per kW-Month	2020 - 2024	0.75		—	1.78	per kW-Month	2019 - 2024

Exit price premiums of 2.1 percent through 13.6 percent are also applied to these contracts and reflect the uncertainty and illiquidity premiums that would be required based on the most recent market activity available for similar type contracts.

Significant increases or decreases in future capacity or forward reserve prices in isolation would decrease or increase, respectively, the fair value of the derivative liability.  Any increases in risk premiums would increase the fair value of the derivative liability.  Changes in these fair values are recorded as a regulatory asset or liability and do not impact net income.  

Valuations using significant unobservable inputs:  The following table presents changes in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis.  The derivative assets and liabilities are presented on a net basis.

CL&P (Millions of Dollars)	For the Years Ended December 31,
	2019			2018
Derivatives, Net:
Fair Value as of Beginning of Period	$	(356.5	)	$	(362.3	)
Net Realized/Unrealized Losses Included in Regulatory Assets	(15.0		)	(32.0		)
Settlements	42.3			37.8
Fair Value as of End of Period	$	(329.2	)	$	(356.5	)

XML

EMPLOYEE BENEFITS - Schedule of Assumptions used To Calculate Pension and SERP and PBOP (Details)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Expected Long-Term Rate of Return	7.00%	7.00%
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Expected Long-Term Rate of Return		8.25%	8.25%
Compensation/Progression Rate		3.50%	3.50%
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Expected Long-Term Rate of Return		8.25%	8.25%
Minimum | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	2.63%	3.85%	3.20%
Expected Long-Term Rate of Return	8.25%
Compensation/Progression Rate	3.50%
Minimum | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	3.85%	3.28%	3.48%
Expected Long-Term Rate of Return	8.25%
Maximum | Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	3.55%	4.62%	3.90%
Compensation/Progression Rate	4.00%	4.00%
Maximum | Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	4.65%	3.94%	4.64%

XML

EMPLOYEE BENEFITS - Schedule of Asset Category (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Pension Plan
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	$ 4,968.6	$ 4,573.9	$ 4,739.5
Uncategorized	4,159.1	4,046.4
Pension Plan | Equity securities
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	1,942.5	1,821.2
Uncategorized	1,349.9	1,377.8
Pension Plan | Fixed Income
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	1,625.2	1,511.8
Uncategorized	1,222.8	1,265.5
Pension Plan | Private Equity
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	988.3	840.1
Uncategorized	971.4	834.0
Pension Plan | Real Assets
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	673.7	632.0
Uncategorized	615.0	569.1
Pension Plan | Total Assets Before 401
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	5,229.7	4,805.1
Pension Plan | 401 PBOP Assets
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	(261.1)	(231.2)
Pension Plan | Fair Value, Inputs, Level 1
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	767.6	597.9
Pension Plan | Fair Value, Inputs, Level 1 | Equity securities
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	592.6	443.4
Pension Plan | Fair Value, Inputs, Level 1 | Fixed Income
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	99.4	85.5
Pension Plan | Fair Value, Inputs, Level 1 | Private Equity
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	16.9	6.1
Pension Plan | Fair Value, Inputs, Level 1 | Real Assets
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	58.7	62.9
Pension Plan | Level 2
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	303.0	160.8
Pension Plan | Level 2 | Equity securities
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	0.0	0.0
Pension Plan | Level 2 | Fixed Income
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	303.0	160.8
Pension Plan | Level 2 | Private Equity
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	0.0	0.0
Pension Plan | Level 2 | Real Assets
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	0.0	0.0
Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	935.9	849.6	$ 922.2
Uncategorized	410.2	436.7
Other Postretirement Benefits Plan | Equity securities
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	345.0	302.4
Uncategorized	187.0	210.5
Other Postretirement Benefits Plan | Fixed Income
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	203.5	185.3
Uncategorized	148.1	123.0
Other Postretirement Benefits Plan | Private Equity
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	26.5	32.7
Uncategorized	26.5	32.7
Other Postretirement Benefits Plan | Real Assets
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	99.8	98.0
Uncategorized	48.6	70.5
Other Postretirement Benefits Plan | Total Assets Before 401
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	674.8	618.4
Other Postretirement Benefits Plan | 401 PBOP Assets
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	261.1	231.2
Other Postretirement Benefits Plan | Fair Value, Inputs, Level 1
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	225.0	141.4
Other Postretirement Benefits Plan | Fair Value, Inputs, Level 1 | Equity securities
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	158.0	91.9
Other Postretirement Benefits Plan | Fair Value, Inputs, Level 1 | Fixed Income
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	15.8	22.0
Other Postretirement Benefits Plan | Fair Value, Inputs, Level 1 | Private Equity
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	0.0	0.0
Other Postretirement Benefits Plan | Fair Value, Inputs, Level 1 | Real Assets
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	51.2	27.5
Other Postretirement Benefits Plan | Level 2
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	39.6	40.3
Other Postretirement Benefits Plan | Level 2 | Equity securities
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	0.0	0.0
Other Postretirement Benefits Plan | Level 2 | Fixed Income
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	39.6	40.3
Other Postretirement Benefits Plan | Level 2 | Private Equity
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	0.0	0.0
Other Postretirement Benefits Plan | Level 2 | Real Assets
Defined Contribution Plan Disclosure [Line Items]
Fair value of pension plan assets	$ 0.0	$ 0.0

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SHORT-TERM DEBT

12 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]

SHORT-TERM DEBT

SHORT-TERM DEBT

Short-Term Debt Borrowing Limits:  The amount of short-term borrowings that may be incurred by CL&P and NSTAR Electric is subject to periodic approval by the FERC.  Because the NHPUC has jurisdiction over PSNH's short-term debt, PSNH is not currently required to obtain FERC approval for its short-term borrowings.  On October 25, 2019, the FERC granted authorization that allows CL&P to issue total short-term borrowings in an aggregate principal amount not to exceed $600 million outstanding at any one time, through December 31, 2021.  On December 18, 2019, the FERC granted authorization that allows NSTAR Electric to issue total short-term borrowings in an aggregate principal amount not to exceed $655 million outstanding at any one time, through December 31, 2021.

PSNH is authorized by regulation of the NHPUC to incur short-term borrowings up to 10 percent of net fixed plant plus an additional $60 million until further ordered by the NHPUC.  As of December 31, 2019, PSNH's short-term debt authorization under the 10 percent of net fixed plant test plus $60 million totaled approximately $354 million.  

CL&P's certificate of incorporation contains preferred stock provisions restricting the amount of unsecured debt that CL&P may incur, including limiting unsecured indebtedness with a maturity of less than 10 years to 10 percent of total capitalization.  As of December 31, 2019, CL&P had $738.1 million of unsecured debt capacity available under this authorization.

Yankee Gas and NSTAR Gas are not required to obtain approval from any state or federal authority to incur short-term debt.

Commercial Paper Programs and Credit Agreements: Eversource parent has a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas and Aquarion Water Company of Connecticut are also parties to a five-year $1.45 billion revolving credit facility. Effective December 9, 2019, the revolving credit facility's termination date was extended for one additional year to December 6, 2024. The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program.

NSTAR Electric has a $650 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. NSTAR Electric is also a party to a five-year $650 million revolving credit facility. Effective December 9, 2019, the revolving credit facility's termination date was extended for one additional year to December 6, 2024. The revolving credit facility serves to backstop NSTAR Electric's $650 million commercial paper program.

The amount of borrowings outstanding and available under the commercial paper programs were as follows:

	Borrowings Outstanding  as of December 31,				Available Borrowing Capacity as of December 31,				Weighted-Average Interest Rate as of December 31,
(Millions of Dollars)	2019		2018		2019		2018		2019		2018
Eversource Parent Commercial Paper Program	$	1,224.9	$	631.5	$	225.1	$	818.5	1.98	%	2.77	%
NSTAR Electric Commercial Paper Program	10.5		278.5		639.5		371.5		1.63	%	2.50	%

There were no borrowings outstanding on either the Eversource parent or NSTAR Electric revolving credit facilities as of December 31, 2019 or 2018.

Amounts outstanding under the commercial paper programs and revolving credit facilities are included in Notes Payable and classified in current liabilities on the Eversource and NSTAR Electric balance sheets as all borrowings are outstanding for no more than 364 days at one time.  As a result of the Eversource parent long-term debt issuance on January 10, 2020, the net proceeds of which were used to repay short-term borrowings outstanding under its commercial paper program, $346.3 million of commercial paper borrowings under the Eversource parent commercial paper program were classified as Long-Term Debt as of December 31, 2019.

Under the credit facilities described above, Eversource and its subsidiaries must comply with certain financial and non-financial covenants, including a consolidated debt to total capitalization ratio.  As of December 31, 2019 and 2018, Eversource and its subsidiaries were in compliance with these covenants. If Eversource or its subsidiaries were not in compliance with these covenants, an event of default would occur requiring all outstanding borrowings by such borrower to be repaid, and additional borrowings by such borrower would not be permitted under its respective credit facility.

The Company expects the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.

Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of December 31, 2019, there were intercompany loans from Eversource parent to CL&P of $63.8 million, to PSNH of $27.0 million, and to a subsidiary of NSTAR Electric of $30.3 million. As of December 31, 2018, there were intercompany loans from Eversource parent to PSNH of $57.0 million. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets.

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INCOME TAXES

12 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

INCOME TAXES

INCOME TAXES

The components of income tax expense are as follows:

Eversource (Millions of Dollars)	For the Years Ended December 31,
	2019			2018			2017
Current Income Taxes:
Federal	$	56.9		$	106.5		$	58.9
State	10.5			10.6			31.6
Total Current	67.4			117.1			90.5
Deferred Income Taxes, Net:
Federal	138.4			122.6			433.0
State	71.4			52.2			58.6
Total Deferred	209.8			174.8			491.6
Investment Tax Credits, Net	(3.7		)	(2.9		)	(3.2		)
Income Tax Expense	$	273.5		$	289.0		$	578.9

	For the Years Ended December 31,
	2019								2018									2017
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH		CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Current Income Taxes:
Federal	$	68.4		$	82.6		$	22.9	$	54.2		$	79.3		$	12.2		$	50.9		$	107.8		$	18.6
State	15.4			18.2			2.2		20.9			30.0			(0.5		)	17.4			25.6			6.2
Total Current	83.8			100.8			25.1		75.1			109.3			11.7			68.3			133.4			24.8
Deferred Income Taxes, Net:
Federal	35.2			0.1			5.8		48.5			27.9			15.4			123.9			88.1			52.7
State	18.8			27.0			10.1		6.4			13.5			20.5			(4.6		)	22.4			11.2
Total Deferred	54.0			27.1			15.9		54.9			41.4			35.9			119.3			110.5			63.9
Investment Tax Credits, Net	(0.8		)	(2.6		)	—		(0.9		)	(1.8		)	—			(1.0		)	(1.8		)	—
Income Tax Expense	$	137.0		$	125.3		$	41.0	$	129.1		$	148.9		$	47.6		$	186.6		$	242.1		$	88.7

A reconciliation between income tax expense and the expected tax expense at the statutory rate is as follows:

Eversource (Millions of Dollars, except percentages)	For the Years Ended December 31,
	2019			2018			2017
Income Before Income Tax Expense	$	1,190.1		$	1,329.5		$	1,574.4
Statutory Federal Income Tax Expense at 21% in 2019 and 2018,   and 35% in 2017	249.9			279.2			551.0
Tax Effect of Differences:
Depreciation	1.9			(30.8		)	(10.8		)
Investment Tax Credit Amortization	(3.7		)	(2.9		)	(3.2		)
State Income Taxes, Net of Federal Impact	24.6			44.4			47.7
Dividends on ESOP	(5.1		)	(5.1		)	(8.4		)
Tax Asset Valuation Allowance/Reserve Adjustments	40.1			5.2			7.0
Excess Stock Benefit	(1.5		)	(1.5		)	(2.9		)
EDIT Amortization	(37.4		)	(5.0		)	—
Other, Net	4.7			5.5			(1.5		)
Income Tax Expense	$	273.5		$	289.0		$	578.9
Effective Tax Rate	23.0		%	21.7		%	36.8		%

	For the Years Ended December 31,
	2019									2018									2017
(Millions of Dollars, except percentages)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Income Before Income Tax Expense	$	547.8		$	557.3		$	175.0		$	506.8		$	532.0		$	163.5		$	563.4		$	616.8		$	224.7
Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017	115.0			117.0			36.8			106.4			111.7			34.3			197.2			215.9			78.6
Tax Effect of Differences:
Depreciation	(0.2		)	(3.0		)	(0.8		)	(1.2		)	(2.8		)	0.1			(5.2		)	(3.0		)	1.1
Investment Tax Credit Amortization	(0.8		)	(2.6		)	—			(0.9		)	(1.8		)	—			(1.0		)	(1.8		)	—
State Income Taxes,   Net of Federal Impact	2.5			35.7			9.8			14.5			33.2			15.8			4.5			31.2			11.3
Tax Asset Valuation   Allowance/Reserve Adjustments	24.5			—			—			7.1			1.2			—			(9.5		)	—			—
Excess Stock Benefit	(0.5		)	(0.5		)	(0.2		)	(0.1		)	(0.1		)	(0.1		)	(0.7		)	(0.7		)	(0.3		)
EDIT Amortization	(5.8		)	(22.9		)	(4.0		)	—			—			(4.4		)	—			—			—
Other, Net	2.3			1.6			(0.6		)	3.3			7.5			1.9			1.3			0.5			(2.0		)
Income Tax Expense	$	137.0		$	125.3		$	41.0		$	129.1		$	148.9		$	47.6		$	186.6		$	242.1		$	88.7
Effective Tax Rate	25.0		%	22.5		%	23.4		%	25.5		%	28.0		%	29.1		%	33.1		%	39.2		%	39.5		%

Eversource, CL&P, NSTAR Electric and PSNH file a consolidated federal income tax return and unitary, combined and separate state income tax returns.  These entities are also parties to a tax allocation agreement under which taxable subsidiaries do not pay any more taxes than they would have otherwise paid had they filed a separate company tax return, and subsidiaries generating tax losses, if any, are paid for their losses when utilized.

Deferred tax assets and liabilities are recognized for the future tax effects of temporary differences between the carrying amounts and the tax basis of assets and liabilities.  The tax effect of temporary differences is accounted for in accordance with the rate-making treatment of the applicable regulatory commissions and relevant accounting authoritative literature.  The tax effects of temporary differences that give rise to the net accumulated deferred income tax obligations are as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Deferred Tax Assets:
Employee Benefits	$	509.4	$	125.4	$	54.8	$	46.7	$	388.2	$	94.5	$	35.0	$	31.1
Derivative Liabilities	105.0		103.6		—		—		111.4		111.4		—		—
Regulatory Deferrals - Liabilities	267.0		37.1		165.7		19.0		299.3		38.6		195.5		16.1
Allowance for Uncollectible Accounts	56.7		25.7		17.7		2.8		54.0		23.1		17.8		3.0
Tax Effect - Tax Regulatory Liabilities	830.4		333.5		280.9		111.3		830.3		336.8		288.9		111.7
Net Operating Loss Carryforwards	9.1		—		—		—		28.5		—		—		0.6
Purchase Accounting Adjustment	58.7		—		—		—		64.2		—		—		—
Other	190.4		92.0		35.8		20.0		166.2		81.1		15.6		33.4
Total Deferred Tax Assets	2,026.7		717.3		554.9		199.8		1,942.1		685.5		552.8		195.9
Less:  Valuation Allowance	43.0		24.9		—		—		19.5		10.7		—		—
Net Deferred Tax Assets	$	1,983.7	$	692.4	$	554.9	$	199.8	$	1,922.6	$	674.8	$	552.8	$	195.9
Deferred Tax Liabilities:
Accelerated Depreciation and Other   Plant-Related Differences	$	3,901.0	$	1,362.2	$	1,391.9	$	428.9	$	3,724.2	$	1,293.3	$	1,342.4	$	410.6
Property Tax Accruals	76.8		36.8		29.0		4.7		73.2		35.4		26.3		5.2
Regulatory Amounts:
Regulatory Deferrals - Assets	1,155.6		340.7		276.2		260.9		1,025.9		320.1		277.4		213.8
Tax Effect - Tax Regulatory Assets	238.2		171.7		11.7		8.3		238.9		167.0		9.7		8.1
Goodwill Regulatory Asset - 1999 Merger	90.6		—		77.8		—		95.2		—		81.7		—
Derivative Assets	19.7		19.7		—		—		20.1		19.9		—		—
Other	257.6		5.9		125.6		3.2		251.1		5.9		109.8		39.4
Total Deferred Tax Liabilities	$	5,739.5	$	1,937.0	$	1,912.2	$	706.0	$	5,428.6	$	1,841.6	$	1,847.3	$	677.1

2017 Federal Legislation: On December 22, 2017, the Tax Cuts and Jobs Act became law, which amended existing federal tax rules and included numerous provisions that impacted corporations.  In particular, the act reduced the U.S. federal corporate income tax rate from 35 percent to 21 percent effective January 1, 2018.  For our regulated companies, the most significant changes are (1) the benefit of incurring a lower federal income tax expense and (2) the reduction in ADIT liabilities (now excess ADIT or EDIT), which are estimated to be approximately $2.8 billion and are included in regulatory liabilities as of December 31, 2019. In 2019, Eversource refunded $51.5 million ($7.9 million at CL&P, $31.5 million at NSTAR Electric, $5.6 million at PSNH, $1.4 million at Yankee Gas and $5.1 million at NSTAR Gas) to customers. See Note 2, "Regulatory Accounting," to the financial statements for further information.

2019 Federal Legislation:  On December 20, 2019, the "Further Consolidated Appropriations Act, 2020," became law, which provided a one-year extension of the production tax credit or the investment tax credit for renewable wind projects under Section 45 of the Internal Revenue Code of 1986 on which construction begins before January 1, 2021. If construction begins on a qualifying wind project in 2020, the project will qualify for a production tax credit of $15 per MWh or an 18 percent investment tax credit. 

Carryforwards:  The following table provides the amounts and expiration dates of state tax credit and loss carryforwards and federal tax credit and net operating loss carryforwards:

	As of December 31,
	2019									2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Expiration Range	Eversource		CL&P		NSTAR Electric		PSNH		Expiration Range
Federal Net Operating Loss	$	19.8	$	—	$	—	$	—	2033 - 2037	$	103.6	$	—	$	—	$	—	2033 - 2037
Federal Charitable Contribution	—		—		—		—		2020 - 2022	2.2		—		—		—		2020 - 2022
State Net   Operating Loss	65.5		—		—		—		2020 - 2038	80.7		—		—		—		2019 - 2038
State Tax Credit	168.1		122.3		—		—		2019 - 2024	148.9		107.0		—		—		2018 - 2023
State Charitable Contribution	9.9		—		—		—		2019 - 2023	9.6		—		—		—		2019 - 2023

In 2019, the company increased its valuation allowance reserve for state credits by $18.5 million ($14.2 million for CL&P), net of tax, to reflect an update for expired tax credits. In 2018, the Company increased its valuation allowance reserve for state credits by $5.2 million ($4.4 million for CL&P), net of tax, to reflect an update for expired tax credits.

For 2019 and 2018, state credit and state loss carryforwards have been partially reserved by a valuation allowance of $43.0 million and $19.5 million (net of tax), respectively.  

Unrecognized Tax Benefits:  A reconciliation of the activity in unrecognized tax benefits, all of which would impact the effective tax rate if recognized, is as follows:

(Millions of Dollars)	Eversource			CL&P
Balance as of January 1, 2017	$	48.4		$	15.3
Gross Increases - Current Year	11.4			4.7
Gross Decreases - Prior Year	(0.9		)	(0.5		)
Lapse of Statute of Limitations	(7.2		)	(1.4		)
Balance as of December 31, 2017	51.7			18.1
Gross Increases - Current Year	9.2			3.2
Gross Decreases - Prior Year	(6.5		)	(0.9		)
Lapse of Statute of Limitations	(8.5		)	(2.2		)
Balance as of December 31, 2018	45.9			18.2
Gross Increases - Current Year	12.1			4.0
Gross Increases - Prior Year	3.4			3.3
Lapse of Statute of Limitations	(6.4		)	(2.4		)
Balance as of December 31, 2019	$	55.0		$	23.1

Interest and Penalties:  Interest on uncertain tax positions is recorded and generally classified as a component of Other Interest Expense on the statements of income.  However, when resolution of uncertainties results in the Company receiving interest income, any related interest benefit is recorded in Other Income, Net on the statements of income.  No penalties have been recorded.  The amount of interest expense/(income) on uncertain tax positions recognized and the related accrued interest payable/(receivable) are as follows:  

	Other Interest Expense/(Income)							Accrued Interest Expense
	For the Years Ended December 31,							As of December 31,
(Millions of Dollars)	2019		2018			2017		2019		2018
Eversource	$	—	$	(1.7	)	$	—	$	0.1	$	0.1

Tax Positions:  During 2019 and 2018, Eversource did not resolve any of its uncertain tax positions.

Open Tax Years:  The following table summarizes Eversource, CL&P, NSTAR Electric and PSNH's tax years that remain subject to examination by major tax jurisdictions as of December 31, 2019:

Description	Tax Years
Federal	2019
Connecticut	2016 - 2019
Massachusetts	2016 - 2019
New Hampshire	2017 - 2019

Eversource does not estimate to have an earnings impact related to unrecognized tax benefits during the next twelve months.

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EMPLOYEE BENEFITS - Summary of RSU and Share Transactions (Details) - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Restricted Stock Units (RSUs)
Units
Beginning balance (in shares)	782,365
Granted (in shares)	271,144
Shares issued (in shares)	(263,219)
Forfeited (in shares)	(16,127)
Ending balance (in shares)	774,163	782,365
Weighted Average Grant-Date Fair Value
Beginning balance (in dollars per share)	$ 50.25
Granted (in dollars per share)	67.91	$ 56.69	$ 55.97
Shares issued (in dollars per share)	55.34
Forfeited (in dollars per share)	63.31
Ending balance (in dollars per share)	$ 54.43	$ 50.25
Performance Shares
Units
Beginning balance (in shares)	499,564
Granted (in shares)	165,022
Shares issued (in shares)	(162,959)
Forfeited (in shares)	(14,720)
Ending balance (in shares)	486,907	499,564
Weighted Average Grant-Date Fair Value
Beginning balance (in dollars per share)	$ 56.08
Granted (in dollars per share)	68.33	$ 56.77	$ 55.70
Shares issued (in dollars per share)	55.69
Forfeited (in dollars per share)	58.20
Ending balance (in dollars per share)	$ 60.30	$ 56.08

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FAIR VALUE OF FINANCIAL INSTRUMENTS

12 Months Ended

Dec. 31, 2019

Fair Value Disclosures [Abstract]

FAIR VALUE OF FINANCIAL INSTRUMENTS

FAIR VALUE OF FINANCIAL INSTRUMENTS

The following methods and assumptions were used to estimate the fair value of each of the following financial instruments:

Preferred Stock, Long-Term Debt and Rate Reduction Bonds:  The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections.  The fair value of long-term debt and RRB debt securities is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields.  The fair values provided in the table below are classified as Level 2 within the fair value hierarchy.  Carrying amounts and estimated fair values are as follows:

	Eversource				CL&P				NSTAR Electric				PSNH
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
As of December 31, 2019:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	162.0	$	116.2	$	117.8	$	43.0	$	44.2	$	—	$	—
Long-Term Debt	14,098.2		15,170.2		3,518.1		4,058.0		3,342.1		3,659.9		951.6		1,005.7
Rate Reduction Bonds	583.3		625.9		—		—		—		—		583.3		625.9
As of December 31, 2018:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	156.8	$	116.2	$	113.8	$	43.0	$	43.0	$	—	$	—
Long-Term Debt	13,086.1		13,154.9		3,254.0		3,429.2		2,944.8		3,024.1		805.2		819.5
Rate Reduction Bonds	635.7		645.8		—		—		—		—		635.7		645.8

Derivative Instruments and Marketable Securities: Derivative instruments and investments in marketable securities are carried at fair value.  For further information, see Note 4, "Derivative Instruments," and Note 5, "Marketable Securities," to the financial statements.  

See Note 1I, "Summary of Significant Accounting Policies – Fair Value Measurements," for the fair value measurement policy and the fair value hierarchy.

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LEASES - Operating Leases Rental Payments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Operating Leased Assets [Line Items]
Operating leases, rent expense	$ 10.8	$ 10.5
CL&P
Operating Leased Assets [Line Items]
Operating leases, rent expense	10.9	11.7
NSTAR Electric
Operating Leased Assets [Line Items]
Operating leases, rent expense	11.8	11.3
PSNH
Operating Leased Assets [Line Items]
Operating leases, rent expense	$ 2.5	$ 3.3

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LEASES - Future Minimum Rental Payments under Operating Leases (Details) $ in Millions	Dec. 31, 2018 USD ($)
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2019	$ 11.5
2020	9.8
2021	8.7
2022	7.2
2023	4.7
Thereafter	32.7
Future minimum lease payments	74.6
CL&P
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2019	1.5
2020	1.4
2021	1.2
2022	1.1
2023	0.5
Thereafter	0.2
Future minimum lease payments	5.9
NSTAR Electric
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2019	7.2
2020	6.0
2021	5.3
2022	4.4
2023	3.1
Thereafter	29.5
Future minimum lease payments	55.5
PSNH
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
2019	0.5
2020	0.4
2021	0.4
2022	0.4
2023	0.2
Thereafter	0.3
Future minimum lease payments	$ 2.2

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PREFERRED STOCK NOT SUBJECT TO MANDATORY REDEMPTION

12 Months Ended

Dec. 31, 2019

Equity [Abstract]

PREFERRED STOCK NOT SUBJECT TO MANDATORY REDEMPTION

PREFERRED STOCK NOT SUBJECT TO MANDATORY REDEMPTION

The CL&P and NSTAR Electric preferred stock is not subject to mandatory redemption and is presented as a noncontrolling interest of a subsidiary in Eversource's financial statements.

CL&P is authorized to issue up to 9,000,000 shares of preferred stock, par value $50 per share, and NSTAR Electric is authorized to issue 2,890,000 shares of preferred stock, par value $100 per share. Holders of preferred stock of CL&P and NSTAR Electric are entitled to receive cumulative dividends in preference to any payment of dividends on the common stock. Upon liquidation, holders of preferred stock of CL&P and NSTAR Electric are entitled to receive a liquidation preference before any distribution to holders of common stock in an amount equal to the par value of the preferred stock plus accrued and unpaid dividends. If the net assets were to be insufficient to pay the liquidation preference in full, then the net assets would be distributed ratably to all holders of preferred stock. The preferred stock of CL&P and NSTAR Electric is subject to optional redemption by the CL&P and NSTAR Electric Boards of Directors at any time.

Details of preferred stock not subject to mandatory redemption are as follows (in millions, except in redemption price and shares):

		Redemption Price Per Share		Shares Outstanding as of December 31,		As of December 31,
Series				2019	2018	2019			2018
CL&P
$1.90	Series of 1947	$	52.50	163,912	163,912	$	8.2		$	8.2
$2.00	Series of 1947	$	54.00	336,088	336,088	16.8			16.8
$2.04	Series of 1949	$	52.00	100,000	100,000	5.0			5.0
$2.20	Series of 1949	$	52.50	200,000	200,000	10.0			10.0
3.90%	Series of 1949	$	50.50	160,000	160,000	8.0			8.0
$2.06	Series E of 1954	$	51.00	200,000	200,000	10.0			10.0
$2.09	Series F of 1955	$	51.00	100,000	100,000	5.0			5.0
4.50%	Series of 1956	$	50.75	104,000	104,000	5.2			5.2
4.96%	Series of 1958	$	50.50	100,000	100,000	5.0			5.0
4.50%	Series of 1963	$	50.50	160,000	160,000	8.0			8.0
5.28%	Series of 1967	$	51.43	200,000	200,000	10.0			10.0
$3.24	Series G of 1968	$	51.84	300,000	300,000	15.0			15.0
6.56%	Series of 1968	$	51.44	200,000	200,000	10.0			10.0
Total CL&P				2,324,000	2,324,000	$	116.2		$	116.2
NSTAR Electric
4.25%	Series of 1956	$	103.625	180,000	180,000	$	18.0		$	18.0
4.78%	Series of 1958	$	102.80	250,000	250,000	25.0			25.0
Total NSTAR Electric				430,000	430,000	$	43.0		$	43.0
Fair Value Adjustment due to Merger with NSTAR						(3.6		)	(3.6		)
Other
6.00%	Series of 1958	$	100.00	23	23	$	—		$	—
Total Eversource - Noncontrolling Interest - Preferred Stock of Subsidiaries						$	155.6		$	155.6

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INCOME TAXES - Interest Expense and Accrued Interest Payable on Uncertain Tax Positions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Other Interest Expense/(Income)	$ 0.0	$ (1.7)	$ 0.0
Accrued Interest Expense	$ 0.1	$ 0.1

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INCOME TAXES - Temporary Differences That Give Rise To Accumulated Deferred Income Tax Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Deferred Tax Assets:
Employee Benefits	$ 509.4	$ 388.2
Derivative Liabilities	105.0	111.4
Regulatory Deferrals - Liabilities	267.0	299.3
Allowance for Uncollectible Accounts	56.7	54.0
Tax Effect - Tax Regulatory Liabilities	830.4	830.3
Federal Net Operating Loss Carryforwards	9.1	28.5
Purchase Accounting Adjustment	58.7	64.2
Other	190.4	166.2
Total Deferred Tax Assets	2,026.7	1,942.1
Less: Valuation Allowance	43.0	19.5
Net Deferred Tax Assets	1,983.7	1,922.6
Deferred Tax Liabilities:
Accelerated Depreciation and Other Plant-Related Differences	3,901.0	3,724.2
Property Tax Accruals	76.8	73.2
Regulatory Amounts:
Regulatory Deferrals - Assets	1,155.6	1,025.9
Tax Effect - Tax Regulatory Assets	238.2	238.9
Goodwill Regulatory Asset - 1999 Merger	90.6	95.2
Derivative Assets	19.7	20.1
Other	257.6	251.1
Total Deferred Tax Liabilities	5,739.5	5,428.6
Regulatory liabilities	4,019.2	3,979.7
Refunds to customers	51.5
EDIT due to Tax Cuts and Jobs Act
Regulatory Amounts:
Regulatory liabilities	2,844.6	2,883.0
CL&P
Deferred Tax Assets:
Employee Benefits	125.4	94.5
Derivative Liabilities	103.6	111.4
Regulatory Deferrals - Liabilities	37.1	38.6
Allowance for Uncollectible Accounts	25.7	23.1
Tax Effect - Tax Regulatory Liabilities	333.5	336.8
Federal Net Operating Loss Carryforwards	0.0	0.0
Purchase Accounting Adjustment	0.0	0.0
Other	92.0	81.1
Total Deferred Tax Assets	717.3	685.5
Less: Valuation Allowance	24.9	10.7
Net Deferred Tax Assets	692.4	674.8
Deferred Tax Liabilities:
Accelerated Depreciation and Other Plant-Related Differences	1,362.2	1,293.3
Property Tax Accruals	36.8	35.4
Regulatory Amounts:
Regulatory Deferrals - Assets	340.7	320.1
Tax Effect - Tax Regulatory Assets	171.7	167.0
Goodwill Regulatory Asset - 1999 Merger	0.0	0.0
Derivative Assets	19.7	19.9
Other	5.9	5.9
Total Deferred Tax Liabilities	1,937.0	1,841.6
Regulatory liabilities	1,247.8	1,231.8
Refunds to customers	7.9
CL&P | EDIT due to Tax Cuts and Jobs Act
Regulatory Amounts:
Regulatory liabilities	1,022.8	1,031.0
NSTAR Electric
Deferred Tax Assets:
Employee Benefits	54.8	35.0
Derivative Liabilities	0.0	0.0
Regulatory Deferrals - Liabilities	165.7	195.5
Allowance for Uncollectible Accounts	17.7	17.8
Tax Effect - Tax Regulatory Liabilities	280.9	288.9
Federal Net Operating Loss Carryforwards	0.0	0.0
Purchase Accounting Adjustment	0.0	0.0
Other	35.8	15.6
Total Deferred Tax Assets	554.9	552.8
Less: Valuation Allowance	0.0	0.0
Net Deferred Tax Assets	554.9	552.8
Deferred Tax Liabilities:
Accelerated Depreciation and Other Plant-Related Differences	1,391.9	1,342.4
Property Tax Accruals	29.0	26.3
Regulatory Amounts:
Regulatory Deferrals - Assets	276.2	277.4
Tax Effect - Tax Regulatory Assets	11.7	9.7
Goodwill Regulatory Asset - 1999 Merger	77.8	81.7
Derivative Assets	0.0	0.0
Other	125.6	109.8
Total Deferred Tax Liabilities	1,912.2	1,847.3
Regulatory liabilities	1,725.8	1,703.9
Refunds to customers	31.5
NSTAR Electric | EDIT due to Tax Cuts and Jobs Act
Regulatory Amounts:
Regulatory liabilities	1,071.2	1,103.7
PSNH
Deferred Tax Assets:
Employee Benefits	46.7	31.1
Derivative Liabilities	0.0	0.0
Regulatory Deferrals - Liabilities	19.0	16.1
Allowance for Uncollectible Accounts	2.8	3.0
Tax Effect - Tax Regulatory Liabilities	111.3	111.7
Federal Net Operating Loss Carryforwards	0.0	0.6
Purchase Accounting Adjustment	0.0	0.0
Other	20.0	33.4
Total Deferred Tax Assets	199.8	195.9
Less: Valuation Allowance	0.0	0.0
Net Deferred Tax Assets	199.8	195.9
Deferred Tax Liabilities:
Accelerated Depreciation and Other Plant-Related Differences	428.9	410.6
Property Tax Accruals	4.7	5.2
Regulatory Amounts:
Regulatory Deferrals - Assets	260.9	213.8
Tax Effect - Tax Regulatory Assets	8.3	8.1
Goodwill Regulatory Asset - 1999 Merger	0.0	0.0
Derivative Assets	0.0	0.0
Other	3.2	39.4
Total Deferred Tax Liabilities	706.0	677.1
Regulatory liabilities	479.2	483.6
Refunds to customers	5.6
PSNH | EDIT due to Tax Cuts and Jobs Act
Regulatory Amounts:
Regulatory liabilities	392.8	$ 396.4
Yankee Gas Services Company
Regulatory Amounts:
Refunds to customers	1.4
NSTAR Gas
Regulatory Amounts:
Refunds to customers	$ 5.1

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EMPLOYEE BENEFITS - Schedule of Compensation Expense and Income Tax Benefit (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation Expense	$ 27.3	$ 21.4	$ 19.7
Future Income Tax Benefit	7.0	5.4	8.0
CL&P
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation Expense	9.8	7.8	7.0
Future Income Tax Benefit	2.5	2.0	2.9
NSTAR Electric
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation Expense	9.7	7.7	7.0
Future Income Tax Benefit	2.5	1.9	2.8
PSNH
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation Expense	3.3	2.9	3.2
Future Income Tax Benefit	$ 0.8	$ 0.7	$ 1.3

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LONG-TERM DEBT - Schedule of Issuances and Repayments (Details) - USD ($) $ in Thousands				1 Months Ended							12 Months Ended
	Nov. 15, 2019	Nov. 01, 2019	Feb. 01, 2019	Jan. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jul. 31, 2019	Jun. 30, 2019	May 31, 2019	Apr. 30, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Repayments of debt											$ (801,078)	$ (1,050,330)	$ (745,000)
Senior Notes
Debt Instrument [Line Items]
Long-term debt					$ 13,770,800						13,770,800	12,248,700
CL&P
Debt Instrument [Line Items]
Repayments of debt											(250,000)	(300,000)	(250,000)
CL&P | Senior Notes | 4.00% 2018 Series A First Mortgage Bonds
Debt Instrument [Line Items]
Issuance										$ 300,000
CL&P | Senior Notes | 3.20% 2017 Series A First Mortgage Bonds
Debt Instrument [Line Items]
Issuance						$ 200,000
CL&P | Senior Notes | 5.50% 2009 Series A First Mortgage Bonds
Debt Instrument [Line Items]
Repayments of debt			$ (250,000)
NSTAR Electric
Debt Instrument [Line Items]
Repayments of debt											0	0	(400,000)
NSTAR Electric | Senior Notes | 3.25% 2019 Debentures
Debt Instrument [Line Items]
Issuance									$ 400,000
PSNH
Debt Instrument [Line Items]
Repayments of debt											(150,000)	(199,250)	(70,000)
PSNH | Senior Notes | 3.60% 2019 Series T First Mortgage Bonds
Debt Instrument [Line Items]
Issuance								$ 300,000
PSNH | Senior Notes | 4.50% 2009 Series P First Mortgage Bonds
Debt Instrument [Line Items]
Repayments of debt					(150,000)
NSTAR Gas | Senior Notes | NSTAR Gas 3.74% Series Q First Mortgage Bonds
Debt Instrument [Line Items]
Issuance							$ 75,000
Yankee Gas | Senior Notes | Yankee Gas 2.23% Series P First Mortgage Bonds
Debt Instrument [Line Items]
Issuance						100,000
Yankee Gas | Senior Notes | Yankee Gas 3.30% Series Q First Mortgage Bonds
Debt Instrument [Line Items]
Issuance						$ 100,000
Yankee Gas | Senior Notes | Yankee Gas 5.26% Series H First Mortgage Bonds
Debt Instrument [Line Items]
Repayments of debt		$ (50,000)
Aquarion | Senior Notes | Aquarion 3.54% Senior Notes
Debt Instrument [Line Items]
Issuance					45,000
Eversource
Debt Instrument [Line Items]
Repayments of debt											(350,000)	$ (450,000)	$ 0
Eversource | Senior Notes | Eversource Parent 4.50% Debentures
Debt Instrument [Line Items]
Repayments of debt	$ (350,000)
Eversource | Senior Notes | Eversource Parent 3.45% Series P Senior Notes | Subsequent Event
Debt Instrument [Line Items]
Issuance				$ 350,000
Eversource | CL&P | Senior Notes | 4.00% 2018 Series A First Mortgage Bonds
Debt Instrument [Line Items]
Long-term debt					800,000						800,000
Eversource | CL&P | Senior Notes | 3.20% 2017 Series A First Mortgage Bonds
Debt Instrument [Line Items]
Long-term debt					$ 500,000						$ 500,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Provision for Uncollectible Accounts (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total Provision for Uncollectible Accounts	$ 224,800	$ 212,700
Provision for Uncollectible Hardship Accounts	143,300	131,500
Uncollectible Expense	63,446	61,337	$ 44,453
CL&P
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total Provision for Uncollectible Accounts	97,300	88,000
Provision for Uncollectible Hardship Accounts	80,100	71,900
Uncollectible Expense	15,948	15,831	5,312
NSTAR Electric
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total Provision for Uncollectible Accounts	75,400	74,500
Provision for Uncollectible Hardship Accounts	43,900	42,500
Uncollectible Expense	25,079	22,279	21,252
PSNH
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total Provision for Uncollectible Accounts	10,500	11,100
Provision for Uncollectible Hardship Accounts	0	0
Uncollectible Expense	$ 6,726	$ 6,383	$ 6,704

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Other Income (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Summary of Accounting Policies [Line Items]
Other Income, Net		$ 132,777	$ 128,366	$ 107,913
Other-than-temporary impairment			32,900
Unrealized gain associated with investment		42,200	3,800	27,400
Pension, SERP and PBOP Non-Service Income Components
Summary of Accounting Policies [Line Items]
Other Income, Net		31,300	60,800	29,900
AFUDC Equity
Summary of Accounting Policies [Line Items]
Other Income, Net		45,000	44,000	34,400
Equity in Earnings of Unconsolidated Affiliates
Summary of Accounting Policies [Line Items]
Other Income, Net		42,200	3,800	27,400
Unrealized gain associated with investment		20,400	17,600	9,700
Investment Income/(Loss)
Summary of Accounting Policies [Line Items]
Other Income, Net		800	(4,000)	7,500
Interest Income
Summary of Accounting Policies [Line Items]
Other Income, Net		12,800	18,100	8,300
Gains on Sales of Property
Summary of Accounting Policies [Line Items]
Other Income, Net		300	5,100	0
Other
Summary of Accounting Policies [Line Items]
Other Income, Net		400	600	400
CL&P
Summary of Accounting Policies [Line Items]
Other Income, Net		17,531	22,663	22,991
CL&P | Pension, SERP and PBOP Non-Service Income Components
Summary of Accounting Policies [Line Items]
Other Income, Net		500	9,500	1,800
CL&P | AFUDC Equity
Summary of Accounting Policies [Line Items]
Other Income, Net		13,200	12,200	12,100
CL&P | Equity in Earnings of Unconsolidated Affiliates
Summary of Accounting Policies [Line Items]
Other Income, Net		100	100	0
CL&P | Investment Income/(Loss)
Summary of Accounting Policies [Line Items]
Other Income, Net		2,300	(3,000)	4,500
CL&P | Interest Income
Summary of Accounting Policies [Line Items]
Other Income, Net		1,500	3,700	4,600
CL&P | Gains on Sales of Property
Summary of Accounting Policies [Line Items]
Other Income, Net		0	0	0
CL&P | Other
Summary of Accounting Policies [Line Items]
Other Income, Net		(100)	200	0
NSTAR Electric
Summary of Accounting Policies [Line Items]
Other Income, Net		44,577	53,066	34,100
NSTAR Electric | Pension, SERP and PBOP Non-Service Income Components
Summary of Accounting Policies [Line Items]
Other Income, Net		23,500	36,000	19,200
NSTAR Electric | AFUDC Equity
Summary of Accounting Policies [Line Items]
Other Income, Net		19,800	15,600	10,200
NSTAR Electric | Equity in Earnings of Unconsolidated Affiliates
Summary of Accounting Policies [Line Items]
Other Income, Net		700	700	300
NSTAR Electric | Investment Income/(Loss)
Summary of Accounting Policies [Line Items]
Other Income, Net		(400)	(500)	2,600
NSTAR Electric | Interest Income
Summary of Accounting Policies [Line Items]
Other Income, Net		700	800	1,800
NSTAR Electric | Gains on Sales of Property
Summary of Accounting Policies [Line Items]
Other Income, Net		100	500	0
NSTAR Electric | Other
Summary of Accounting Policies [Line Items]
Other Income, Net		200	0	0
PSNH
Summary of Accounting Policies [Line Items]
Other Income, Net		19,222	27,672	9,805
PSNH | Pension, SERP and PBOP Non-Service Income Components
Summary of Accounting Policies [Line Items]
Other Income, Net		4,900	9,900	5,900
PSNH | AFUDC Equity
Summary of Accounting Policies [Line Items]
Other Income, Net		3,400	0	0
PSNH | Equity in Earnings of Unconsolidated Affiliates
Summary of Accounting Policies [Line Items]
Other Income, Net		0	0	0
PSNH | Investment Income/(Loss)
Summary of Accounting Policies [Line Items]
Other Income, Net		300	(800)	1,600
PSNH | Interest Income
Summary of Accounting Policies [Line Items]
Other Income, Net		10,500	14,100	2,200
PSNH | Gains on Sales of Property
Summary of Accounting Policies [Line Items]
Other Income, Net		0	4,400	0
PSNH | Other
Summary of Accounting Policies [Line Items]
Other Income, Net		100	100	$ 100
Deferred Storm Restoration Costs | PSNH
Summary of Accounting Policies [Line Items]
Other Income, Net	$ 5,200	$ 6,300	$ 8,700

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RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES - Income Statement (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Income Statements, Captions [Line Items]
Interest Expense on RRB Principal (included in Interest Expense)	$ 533,197	$ 498,805	$ 421,755
PSNH
Condensed Income Statements, Captions [Line Items]
Amortization of Regulatory Assets, Net	57,732	80,978	(16,577)
Interest Expense on RRB Principal (included in Interest Expense)	60,666	60,634	$ 51,007
Variable Interest Entity, Primary Beneficiary | Rate Reduction Bonds | PSNH
Condensed Income Statements, Captions [Line Items]
Amortization of Regulatory Assets, Net	43,000	27,300
Interest Expense on RRB Principal (included in Interest Expense)	$ 21,100	$ 14,400

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EMPLOYEE BENEFITS - Schedule of Actuarial Assumptions (Details)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Compensation/Progression Rate		4.00%
Pension Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	3.04%	4.22%
Compensation/Progression Rate	3.50%	3.50%
Pension Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	3.35%	4.45%
Compensation/Progression Rate	4.00%	4.00%
Other Postretirement Benefits Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	3.26%	4.38%
Other Postretirement Benefits Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Discount Rate	3.28%	4.41%
Pre-65 Plan | Other Postretirement Benefits Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Health care trend rate	3.50%
Pre-65 Plan | Other Postretirement Benefits Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Health care trend rate	6.50%
Post-65 Plan | Other Postretirement Benefits Plan | Minimum
Defined Benefit Plan Disclosure [Line Items]
Health care trend rate	3.50%
Post-65 Plan | Other Postretirement Benefits Plan | Maximum
Defined Benefit Plan Disclosure [Line Items]
Health care trend rate	5.00%

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REGULATORY ACCOUNTING - Components of Regulatory Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 5,514,700	$ 5,145,900
Less: Current Portion	651,112	514,779
Total Long-Term Regulatory Assets	4,863,639	4,631,137
Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	2,382,900	1,914,800
Income Taxes, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	725,800	728,600
Securitized Stranded Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	565,300	608,400
Storm Restoration Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	540,600	576,000
Regulatory Tracker Mechanisms
Regulatory Assets [Line Items]
Total Regulatory Assets	411,500	316,000
Derivative Liabilities
Regulatory Assets [Line Items]
Total Regulatory Assets	334,500	356,500
Goodwill-related
Regulatory Assets [Line Items]
Total Regulatory Assets	331,500	348,400
Asset Retirement Obligations
Regulatory Assets [Line Items]
Total Regulatory Assets	97,200	89,200
Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	125,400	208,000
CL&P
Regulatory Assets [Line Items]
Total Regulatory Assets	1,735,900	1,630,700
Less: Current Portion	178,607	125,155
Total Long-Term Regulatory Assets	1,557,261	1,505,488
CL&P | Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	539,000	424,700
CL&P | Income Taxes, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	458,800	454,400
CL&P | Securitized Stranded Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
CL&P | Storm Restoration Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	274,600	302,600
CL&P | Regulatory Tracker Mechanisms
Regulatory Assets [Line Items]
Total Regulatory Assets	78,300	33,200
CL&P | Derivative Liabilities
Regulatory Assets [Line Items]
Total Regulatory Assets	329,200	356,500
CL&P | Goodwill-related
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
CL&P | Asset Retirement Obligations
Regulatory Assets [Line Items]
Total Regulatory Assets	30,800	32,300
CL&P | Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	25,200	27,000
NSTAR Electric
Regulatory Assets [Line Items]
Total Regulatory Assets	1,535,600	1,438,200
Less: Current Portion	285,591	241,747
Total Long-Term Regulatory Assets	1,250,029	1,196,512
NSTAR Electric | Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	629,800	544,400
NSTAR Electric | Income Taxes, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	108,000	105,900
NSTAR Electric | Securitized Stranded Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
NSTAR Electric | Storm Restoration Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	200,600	212,900
NSTAR Electric | Regulatory Tracker Mechanisms
Regulatory Assets [Line Items]
Total Regulatory Assets	207,100	169,100
NSTAR Electric | Derivative Liabilities
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
NSTAR Electric | Goodwill-related
Regulatory Assets [Line Items]
Total Regulatory Assets	284,600	299,100
NSTAR Electric | Asset Retirement Obligations
Regulatory Assets [Line Items]
Total Regulatory Assets	50,300	42,200
NSTAR Electric | Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	55,200	64,600
PSNH
Regulatory Assets [Line Items]
Total Regulatory Assets	945,800	929,500
Less: Current Portion	84,053	67,228
Total Long-Term Regulatory Assets	861,672	862,288
PSNH | Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	218,200	169,600
PSNH | Income Taxes, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	12,800	8,300
PSNH | Securitized Stranded Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	565,300	608,400
PSNH | Storm Restoration Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	65,400	60,500
PSNH | Regulatory Tracker Mechanisms
Regulatory Assets [Line Items]
Total Regulatory Assets	65,800	67,300
PSNH | Derivative Liabilities
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
PSNH | Goodwill-related
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
PSNH | Asset Retirement Obligations
Regulatory Assets [Line Items]
Total Regulatory Assets	3,600	3,300
PSNH | Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 14,700	$ 12,100

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QUARTERLY FINANCIAL DATA (UNAUDITED) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Quarterly Financial Data [Line Items]
Operating Revenues	$ 2,050,400	$ 2,175,800	$ 1,884,500	$ 2,415,800	$ 2,034,900	$ 2,271,400	$ 1,853,900	$ 2,288,000	$ 8,526,470	$ 8,448,201	$ 7,751,952
Operating Income	435,600	509,200	151,000	494,700	400,000	466,000	391,400	442,500	1,590,491	1,699,930	1,888,249
Net Income	251,900	320,800	33,300	310,600	233,200	291,300	244,600	271,400	916,572	1,040,519	995,515
Net Income Attributable to Common Shareholders	$ 250,000	$ 318,900	$ 31,500	$ 308,700	$ 231,300	$ 289,400	$ 242,800	$ 269,500	$ 909,053	$ 1,033,000	$ 987,996
Basic EPS (in dollars per share)	$ 0.77	$ 0.98	$ 0.10	$ 0.97	$ 0.73	$ 0.91	$ 0.76	$ 0.85	$ 2.83	$ 3.25	$ 3.11
Diluted EPS (in dollars per share)	$ 0.76	$ 0.98	$ 0.10	$ 0.97	$ 0.73	$ 0.91	$ 0.76	$ 0.85	$ 2.81	$ 3.25	$ 3.11
Impairment of Northern Pass Transmission			$ 239,600						$ 239,644	$ 0	$ 0
CL&P
Quarterly Financial Data [Line Items]
Operating Revenues	$ 788,700	$ 853,900	740,800	$ 849,200	$ 751,300	$ 865,000	$ 694,900	$ 785,000	3,232,551	3,096,174	2,887,359
Operating Income	152,700	190,300	166,800	171,800	142,800	172,700	163,100	157,200	681,649	635,837	683,354
Net Income	83,900	111,700	104,800	110,500	79,100	100,300	99,700	98,600	410,852	377,717	376,726
NSTAR Electric
Quarterly Financial Data [Line Items]
Operating Revenues	686,400	878,700	681,900	797,600	712,600	939,500	690,700	770,100	3,044,642	3,112,926	2,980,629
Operating Income	135,500	219,400	134,200	137,800	126,000	205,500	133,600	119,000	626,890	584,123	688,440
Net Income	93,400	154,900	89,700	94,000	77,500	140,600	87,900	77,100	431,956	383,090	374,726
PSNH
Quarterly Financial Data [Line Items]
Operating Revenues	268,200	280,400	240,900	276,400	254,900	290,200	235,100	267,400	1,065,936	1,047,619	981,624
Operating Income	56,000	64,500	46,300	49,700	37,200	56,500	46,900	55,800	216,467	196,414	265,873
Net Income	$ 33,400	$ 40,900	$ 26,900	$ 32,800	$ 14,300	$ 40,700	$ 25,800	$ 35,100	$ 134,048	$ 115,876	$ 135,996

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RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES (Tables)

12 Months Ended

Dec. 31, 2019

Rate Reduction Bonds and Variable Interest Entity [Abstract]

Summary of the Impact of Funding on the Balance Sheets and Income Statements

The following tables summarize the impact of PSNH Funding on PSNH's balance sheets and income statements:

(Millions of Dollars)
Balance Sheet:	As of December 31, 2019		As of December 31, 2018
Restricted Cash - Current Portion (included in Current Assets)	$	32.5	$	47.5
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2
Securitized Stranded Cost (included in Regulatory Assets)	565.3		608.4
Other Regulatory Liabilities (included in Regulatory Liabilities)	5.6		5.8
Accrued Interest (included in Other Current Liabilities)	8.6		14.4
Rate Reduction Bonds - Current Portion	43.2		52.3
Rate Reduction Bonds - Long-Term Portion	540.1		583.3

(Millions of Dollars) Income Statement:	For the Year Ended December 31, 2019		For the Year Ended December 31, 2018
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	$	43.0	$	27.3
Interest Expense on RRB Principal (included in Interest Expense)	21.1		14.4

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ASSET RETIREMENT OBLIGATIONS (Tables)

12 Months Ended

Dec. 31, 2019

Asset Retirement Obligation Disclosure [Abstract]

Schedule of Change in Asset Retirement Obligation

A reconciliation of the beginning and ending carrying amounts of ARO liabilities is as follows:

	As of December 31,
	2019											2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH		Eversource			CL&P		NSTAR Electric		PSNH
Balance as of Beginning of Year	$	466.2		$	33.5		$	72.4		$	4.0	$	419.1		$	31.5	$	44.6	$	25.0
Liabilities Incurred During the Year	30.3			—			30.3			—		11.3			—		11.3		—
Liabilities Settled During the Year	(21.3		)	(3.6		)	—			—		(36.6		)	—		—		(21.5		)
Accretion	27.1			2.2			3.5			0.2		25.5			2.0		2.2		0.5
Revisions in Estimated Cash Flows	(12.8		)	(0.1		)	(8.7		)	—		46.9			—		14.3		—
Balance as of End of Year	$	489.5		$	32.0		$	97.5		$	4.2	$	466.2		$	33.5	$	72.4	$	4.0

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SEGMENT INFORMATION - Schedule of Segment Information (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Operating Revenues	$ 2,050,400	$ 2,175,800	$ 1,884,500	$ 2,415,800	$ 2,034,900	$ 2,271,400	$ 1,853,900	$ 2,288,000	$ 8,526,470	$ 8,448,201	$ 7,751,952
Depreciation and Amortization									(1,080,700)	(1,072,000)	(863,800)
Impairment of Northern Pass Transmission			(239,600)						(239,644)	0	0
Other Operating Expenses									(5,615,700)	(5,676,300)	(5,000,000)
Operating Income	435,600	509,200	151,000	494,700	400,000	466,000	391,400	442,500	1,590,491	1,699,930	1,888,249
Interest Expense									(533,197)	(498,805)	(421,755)
Interest Income									12,800	18,100	8,300
Other Income/(Loss), Net									120,000	110,300	99,700
Income Tax (Expense)/Benefit									(273,499)	(288,972)	(578,892)
Net Income	251,900	320,800	33,300	310,600	233,200	291,300	244,600	271,400	916,572	1,040,519	995,515
Net Income Attributable to Noncontrolling Interests									(7,519)	(7,519)	(7,519)
Net Income/(Loss) Attributable to Common Shareholders	250,000	$ 318,900	$ 31,500	$ 308,700	231,300	$ 289,400	$ 242,800	$ 269,500	909,053	1,033,000	987,996
Total Assets (as of)	41,123,915				38,241,256				41,123,915	38,241,256
Cash Flows Used for Investments in Plant									2,911,489	2,569,936	2,348,105
Operating Segments | Electric Distribution
Segment Reporting Information [Line Items]
Operating Revenues									6,976,500	6,957,200	5,542,900
Depreciation and Amortization									(651,300)	(671,800)	(542,600)
Impairment of Northern Pass Transmission									0
Other Operating Expenses									(5,525,100)	(5,548,600)	(4,072,600)
Operating Income									800,100	736,800	927,700
Interest Expense									(206,400)	(202,800)	(186,300)
Interest Income									13,300	18,700	7,300
Other Income/(Loss), Net									46,800	67,500	41,600
Income Tax (Expense)/Benefit									(135,900)	(160,200)	(288,300)
Net Income									517,900	460,000	502,000
Net Income Attributable to Noncontrolling Interests									(4,600)	(4,600)	(4,600)
Net Income/(Loss) Attributable to Common Shareholders									513,300	455,400	497,400
Total Assets (as of)	22,541,900				21,389,100				22,541,900	21,389,100
Cash Flows Used for Investments in Plant									1,104,200	961,300	1,020,700
Operating Segments | Natural Gas Distribution
Segment Reporting Information [Line Items]
Operating Revenues									1,062,200	1,022,200	947,300
Depreciation and Amortization									(68,300)	(75,000)	(72,900)
Impairment of Northern Pass Transmission									0
Other Operating Expenses									(830,800)	(787,600)	(716,400)
Operating Income									163,100	159,600	158,000
Interest Expense									(47,400)	(44,100)	(43,100)
Interest Income									100	0	100
Other Income/(Loss), Net									1,600	7,100	3,800
Income Tax (Expense)/Benefit									(21,200)	(29,400)	(44,200)
Net Income									96,200	93,200	74,600
Net Income Attributable to Noncontrolling Interests									0	0	0
Net Income/(Loss) Attributable to Common Shareholders									96,200	93,200	74,600
Total Assets (as of)	4,345,500				3,904,900				4,345,500	3,904,900
Cash Flows Used for Investments in Plant									460,200	351,500	298,200
Operating Segments | Electric Transmission
Segment Reporting Information [Line Items]
Operating Revenues									1,389,000	1,286,300	1,301,700
Depreciation and Amortization									(253,300)	(231,800)	(209,400)
Impairment of Northern Pass Transmission									(239,600)
Other Operating Expenses									(411,200)	(375,500)	(382,800)
Operating Income									484,900	679,000	709,500
Interest Expense									(125,700)	(120,600)	(115,100)
Interest Income									1,500	2,400	1,800
Other Income/(Loss), Net									29,200	31,100	27,300
Income Tax (Expense)/Benefit									(130,500)	(161,800)	(228,700)
Net Income									259,400	430,100	394,800
Net Income Attributable to Noncontrolling Interests									(2,900)	(2,900)	(2,900)
Net Income/(Loss) Attributable to Common Shareholders									256,500	427,200	391,900
Total Assets (as of)	10,904,000				10,285,000				10,904,000	10,285,000
Cash Flows Used for Investments in Plant									987,000	976,200	867,600
Operating Segments | Water Distribution
Segment Reporting Information [Line Items]
Operating Revenues									214,600	212,000	15,900
Depreciation and Amortization									(46,900)	(46,500)	(3,700)
Impairment of Northern Pass Transmission									0
Other Operating Expenses									(101,000)	(99,800)	(8,300)
Operating Income									66,700	65,700	3,900
Interest Expense									(34,600)	(34,300)	(3,100)
Interest Income									0	0	100
Other Income/(Loss), Net									400	(400)	0
Income Tax (Expense)/Benefit									2,400	(100)	(2,100)
Net Income									34,900	30,900	(1,200)
Net Income Attributable to Noncontrolling Interests									0	0	0
Net Income/(Loss) Attributable to Common Shareholders									34,900	30,900	(1,200)
Total Assets (as of)	2,351,700				2,253,000				2,351,700	2,253,000
Cash Flows Used for Investments in Plant									118,000	102,300	16,000
Other
Segment Reporting Information [Line Items]
Operating Revenues									1,028,500	936,300	931,000
Depreciation and Amortization									(63,200)	(49,100)	(37,400)
Impairment of Northern Pass Transmission									0
Other Operating Expenses									(891,300)	(831,500)	(806,600)
Operating Income									74,000	55,700	87,000
Interest Expense									(170,300)	(129,300)	(90,000)
Interest Income									48,700	30,300	15,700
Other Income/(Loss), Net									1,041,500	1,185,300	1,113,000
Income Tax (Expense)/Benefit									11,700	62,500	(15,500)
Net Income									1,005,600	1,204,500	1,110,200
Net Income Attributable to Noncontrolling Interests									0	0	0
Net Income/(Loss) Attributable to Common Shareholders									1,005,600	1,204,500	1,110,200
Total Assets (as of)	20,469,600				17,874,200				20,469,600	17,874,200
Cash Flows Used for Investments in Plant									242,100	178,600	145,600
Eliminations
Segment Reporting Information [Line Items]
Operating Revenues									(2,144,300)	(1,965,800)	(986,800)
Depreciation and Amortization									2,300	2,200	2,200
Impairment of Northern Pass Transmission									0
Other Operating Expenses									2,143,700	1,966,700	986,700
Operating Income									1,700	3,100	2,100
Interest Expense									51,200	32,300	15,800
Interest Income									(50,800)	(33,300)	(16,700)
Other Income/(Loss), Net									(999,500)	(1,180,300)	(1,086,000)
Income Tax (Expense)/Benefit									0	0	(100)
Net Income									(997,400)	(1,178,200)	(1,084,900)
Net Income Attributable to Noncontrolling Interests									0	0	0
Net Income/(Loss) Attributable to Common Shareholders									(997,400)	(1,178,200)	(1,084,900)
Total Assets (as of)	$ (19,488,800)				$ (17,464,900)				(19,488,800)	(17,464,900)
Cash Flows Used for Investments in Plant									$ 0	$ 0	$ 0

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EARNINGS PER SHARE - Components of Basic and Diluted EPS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Earnings Per Share [Abstract]
Net Income Attributable to Common Shareholders	$ 250,000	$ 318,900	$ 31,500	$ 308,700	$ 231,300	$ 289,400	$ 242,800	$ 269,500	$ 909,053	$ 1,033,000	$ 987,996
Weighted Average Common Shares Outstanding:
Basic (in shares)									321,416,086	317,370,369	317,411,097
Dilutive Effect of:
Share-Based Compensation Awards and Other (in shares)									762,215	623,565	620,483
Equity Forward Sale Agreement (in shares)									763,335	0	0
Dilutive Effect (in shares)									1,525,550	623,565	620,483
Diluted (in shares)									322,941,636	317,993,934	318,031,580
Basic EPS (in dollars per share)	$ 0.77	$ 0.98	$ 0.10	$ 0.97	$ 0.73	$ 0.91	$ 0.76	$ 0.85	$ 2.83	$ 3.25	$ 3.11
Diluted EPS (in dollars per share)	$ 0.76	$ 0.98	$ 0.10	$ 0.97	$ 0.73	$ 0.91	$ 0.76	$ 0.85	$ 2.81	$ 3.25	$ 3.11

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QUARTERLY FINANCIAL DATA (UNAUDITED) (Tables)

12 Months Ended

Dec. 31, 2019

Quarterly Financial Data [Abstract]

Schedule of Quarterly Financial Information

	Quarter Ended
Eversource (Millions of Dollars, except   per share information)	2019								2018
	March 31,		June 30, (2)		September 30,		December 31,		March 31,		June 30,		September 30,		December 31,
Operating Revenues	$	2,415.8	$	1,884.5	$	2,175.8	$	2,050.4	$	2,288.0	$	1,853.9	$	2,271.4	$	2,034.9
Operating Income	494.7		151.0		509.2		435.6		442.5		391.4		466.0		400.0
Net Income	310.6		33.3		320.8		251.9		271.4		244.6		291.3		233.2
Net Income Attributable   to Common Shareholders	308.7		31.5		318.9		250.0		269.5		242.8		289.4		231.3
Basic EPS (1)	$	0.97	$	0.10	$	0.98	$	0.77	$	0.85	$	0.76	$	0.91	$	0.73
Diluted EPS (1)	$	0.97	$	0.10	$	0.98	$	0.76	$	0.85	$	0.76	$	0.91	$	0.73

⁽¹⁾    The summation of quarterly EPS data may not equal annual data due to rounding.

⁽²⁾  In the second quarter of 2019, Eversource recorded an impairment charge related to NPT of $239.6 million within Operating Income on the statement of income. For further information, see Note 1D, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements.

	Quarter Ended
	2019								2018
(Millions of Dollars)	March 31,		June 30,		September 30,		December 31,		March 31,		June 30,		September 30,		December 31,
CL&P
Operating Revenues	$	849.2	$	740.8	$	853.9	$	788.7	$	785.0	$	694.9	$	865.0	$	751.3
Operating Income	171.8		166.8		190.3		152.7		157.2		163.1		172.7		142.8
Net Income	110.5		104.8		111.7		83.9		98.6		99.7		100.3		79.1
NSTAR Electric
Operating Revenues	$	797.6	$	681.9	$	878.7	$	686.4	$	770.1	$	690.7	$	939.5	$	712.6
Operating Income	137.8		134.2		219.4		135.5		119.0		133.6		205.5		126.0
Net Income	94.0		89.7		154.9		93.4		77.1		87.9		140.6		77.5
PSNH
Operating Revenues	$	276.4	$	240.9	$	280.4	$	268.2	$	267.4	$	235.1	$	290.2	$	254.9
Operating Income	49.7		46.3		64.5		56.0		55.8		46.9		56.5		37.2
Net Income	32.8		26.9		40.9		33.4		35.1		25.8		40.7		14.3

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ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Related tax effect recognized in AOCI	$ 4.4	$ (0.2)	$ 4.1
Pre-tax amount reclassified from AOCI as a decrease to net income	2.5
Pre-tax amount reclassified from AOCI as a decrease to net income as a result of amortization of Pension, SERP and PBOP costs	7.8
NSTAR Gas
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Pre-tax amount reclassified from AOCI as a decrease to net income	0.7
PSNH
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Pre-tax amount reclassified from AOCI as a decrease to net income	$ 1.8

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

12 Months Ended

Dec. 31, 2019

Fair Value Disclosures [Abstract]

Carrying Amounts and Estimated Fair Values of Financial Instruments

The fair values provided in the table below are classified as Level 2 within the fair value hierarchy.  Carrying amounts and estimated fair values are as follows:

	Eversource				CL&P				NSTAR Electric				PSNH
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
As of December 31, 2019:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	162.0	$	116.2	$	117.8	$	43.0	$	44.2	$	—	$	—
Long-Term Debt	14,098.2		15,170.2		3,518.1		4,058.0		3,342.1		3,659.9		951.6		1,005.7
Rate Reduction Bonds	583.3		625.9		—		—		—		—		583.3		625.9
As of December 31, 2018:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	156.8	$	116.2	$	113.8	$	43.0	$	43.0	$	—	$	—
Long-Term Debt	13,086.1		13,154.9		3,254.0		3,429.2		2,944.8		3,024.1		805.2		819.5
Rate Reduction Bonds	635.7		645.8		—		—		—		—		635.7		645.8

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EARNINGS PER SHARE (Tables)

12 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

Components of Basic and Diluted EPS

The following table sets forth the components of basic and diluted EPS:

Eversource (Millions of Dollars, except share information)	For the Years Ended December 31,
	2019		2018		2017
Net Income Attributable to Common Shareholders	$	909.1	$	1,033.0	$	988.0
Weighted Average Common Shares Outstanding:
Basic	321,416,086		317,370,369		317,411,097
Dilutive Effect of:
Share-Based Compensation Awards and Other	762,215		623,565		620,483
Equity Forward Sale Agreement	763,335		—		—
Total Dilutive Effect	1,525,550		623,565		620,483
Diluted	322,941,636		317,993,934		318,031,580
Basic EPS	$	2.83	$	3.25	$	3.11
Diluted EPS	$	2.81	$	3.25	$	3.11

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PREFERRED STOCK NOT SUBJECT TO MANDATORY REDEMPTION - Narrative (Details)	Dec. 31, 2019 $ / shares shares
CL&P
Class of Stock [Line Items]
Preferred stock, shares authorized (in shares) | shares	9,000,000
Preferred stock, par value (in dollars per share) | $ / shares	$ 50
NSTAR Electric
Class of Stock [Line Items]
Preferred stock, shares authorized (in shares) | shares	2,890,000
Preferred stock, par value (in dollars per share) | $ / shares	$ 100

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INVESTMENTS IN UNCONSOLIDATED AFFILIATES - Narrative (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2019 USD ($) company	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)	Feb. 08, 2019 mi²
Schedule of Equity Method Investments [Line Items]
Equity in earnings of unconsolidated affiliates, net of impairment	$ 42,200	$ 3,800	$ 27,400
Dividends received from equity method investees	$ 48,900	22,300	20,000
Number of companies that transmit hydro electricity imported from The Hydro-Quebec System in Canada | company	2
Payments to acquire investments	$ 416,337	205,150	$ 32,634
Other-than-temporary impairment		32,900
Offshore Wind Business - North East Offshore and Bay State Wind
Schedule of Equity Method Investments [Line Items]
Carrying amount of equity method investments in excess of the underlying equity in net assets	240,300	7,200
Goodwill	$ 168,300
Ownership interest	50.00%
Revolution Wind And South Fork Wind
Schedule of Equity Method Investments [Line Items]
Ownership interest				50.00%
Area of land (in square miles) | mi²				257
Bay State Wind
Schedule of Equity Method Investments [Line Items]
Ownership interest				50.00%
Area of land (in square miles) | mi²				300
Hydro-Quebec System
Schedule of Equity Method Investments [Line Items]
Ownership interest	14.50%
Payments to acquire investments	$ 8,200	$ 7,600

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DERIVATIVE INSTRUMENTS - Schedule of Gross Fair Value of Contracts (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Level 2 | Current Derivative Assets
Current and Long-Term Derivative Assets
Commodity Supply and Price Risk Management	$ 0.0	$ 1.5
Netting	0.0	(0.9)
Net Amount Recorded as a Derivative	0.0	0.6
Level 2 | Current Derivative Liabilities
Current and Long-Term Derivative Liabilities
Commodity Supply and Price Risk Management	(5.2)	0.0
Netting	0.0	0.0
Net Amount Recorded as a Derivative	(5.2)	0.0
Level 2 | Long-Term Derivative Liabilities:
Current and Long-Term Derivative Liabilities
Commodity Supply and Price Risk Management	(0.1)	0.0
Netting	0.0	0.0
Net Amount Recorded as a Derivative	(0.1)	0.0
CL&P | Level 3 | Current Derivative Assets
Current and Long-Term Derivative Assets
Commodity Supply and Price Risk Management	12.2	9.6
Netting	(0.4)	(3.4)
Net Amount Recorded as a Derivative	11.8	6.2
CL&P | Level 3 | Long-Term Derivative Assets
Current and Long-Term Derivative Assets
Commodity Supply and Price Risk Management	67.5	74.2
Netting	(2.1)	(2.3)
Net Amount Recorded as a Derivative	65.4	71.9
CL&P | Level 3 | Current Derivative Liabilities
Current and Long-Term Derivative Liabilities
Commodity Supply and Price Risk Management	(67.8)	(55.1)
Netting	0.0	0.0
Net Amount Recorded as a Derivative	(67.8)	(55.1)
CL&P | Level 3 | Long-Term Derivative Liabilities:
Current and Long-Term Derivative Liabilities
Commodity Supply and Price Risk Management	(338.6)	(379.5)
Netting	0.0	0.0
Net Amount Recorded as a Derivative	$ (338.6)	$ (379.5)

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REGULATORY ACCOUNTING - FERC ROE Complaints (Details) - FERC ROE First and Second Complaints $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($)
Regulatory Assets [Line Items]
Cumulative pre-tax reserves which include impact of refunds given to customers	$ 39.1
CL&P
Regulatory Assets [Line Items]
Cumulative pre-tax reserves which include impact of refunds given to customers	21.4
NSTAR Electric
Regulatory Assets [Line Items]
Cumulative pre-tax reserves which include impact of refunds given to customers	14.6
PSNH
Regulatory Assets [Line Items]
Cumulative pre-tax reserves which include impact of refunds given to customers	$ 3.1

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MARKETABLE SECURITIES - Fair Value Measurement (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	$ 462.6	$ 430.4
Fair Value, Inputs, Level 1
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	274.5	269.9
Fair Value, Inputs, Level 1 | Mutual Funds and Equities
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	228.5	244.0
Fair Value, Inputs, Level 1 | Money Market Funds
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	46.0	25.9
Level 2
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	188.1	160.5
Level 2 | U.S. Government Issued Debt Securities (Agency and Treasury)
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	96.8	79.6
Level 2 | Corporate Debt Securities
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	44.0	39.5
Level 2 | Asset-Backed Debt Securities
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	12.9	14.0
Level 2 | Municipal Bonds
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	26.7	19.2
Level 2 | Other Fixed Income Securities
Debt and Equity Securities, FV-NI [Line Items]
Total Marketable Securities	$ 7.7	$ 8.2

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ASSET RETIREMENT OBLIGATIONS

12 Months Ended

Dec. 31, 2019

Asset Retirement Obligation Disclosure [Abstract]

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS

Eversource, including CL&P, NSTAR Electric and PSNH, recognizes a liability for the fair value of an ARO on the obligation date if the liability's fair value can be reasonably estimated, even if it is conditional on a future event.  Settlement dates and future costs are reasonably estimated when sufficient information becomes available.  Management has identified various categories of AROs, primarily CYAPC's and YAEC's obligation to dispose of spent nuclear fuel and high level waste, and also certain assets containing asbestos and hazardous contamination. Management has performed fair value calculations reflecting expected probabilities for settlement scenarios.

The fair value of an ARO is recorded as a liability in Other Long-Term Liabilities with a corresponding amount included in Property, Plant and Equipment, Net on the balance sheets.  The ARO assets are depreciated, and the ARO liabilities are accreted over the estimated life of the obligation and the corresponding credits are recorded as accumulated depreciation and ARO liabilities, respectively.  As the electric and natural gas companies are rate-regulated on a cost-of-service basis, these companies apply regulatory accounting guidance and both the depreciation and accretion costs associated with these companies' AROs are recorded as increases to Regulatory Assets on the balance sheets.  

A reconciliation of the beginning and ending carrying amounts of ARO liabilities is as follows:

	As of December 31,
	2019											2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH		Eversource			CL&P		NSTAR Electric		PSNH
Balance as of Beginning of Year	$	466.2		$	33.5		$	72.4		$	4.0	$	419.1		$	31.5	$	44.6	$	25.0
Liabilities Incurred During the Year	30.3			—			30.3			—		11.3			—		11.3		—
Liabilities Settled During the Year	(21.3		)	(3.6		)	—			—		(36.6		)	—		—		(21.5		)
Accretion	27.1			2.2			3.5			0.2		25.5			2.0		2.2		0.5
Revisions in Estimated Cash Flows	(12.8		)	(0.1		)	(8.7		)	—		46.9			—		14.3		—
Balance as of End of Year	$	489.5		$	32.0		$	97.5		$	4.2	$	466.2		$	33.5	$	72.4	$	4.0

The ARO balance includes the current portion of $1.0 million for Eversource and NSTAR Electric as of December 31, 2019, which is included in Other Current Liabilities on the balance sheets.

Eversource's amounts include CYAPC and YAEC's AROs of $337.7 million and $339.9 million as of December 31, 2019 and 2018, respectively. The fair value of the ARO for CYAPC and YAEC includes uncertainties of the fuel off-load dates related to the DOE's timing of performance regarding its obligation to dispose of the spent nuclear fuel and high level waste and other assumptions, including discount rates.  The incremental asset recorded as an offset to the ARO liability was fully depreciated since the plants have no remaining useful life.  Any changes in the ARO liability are recorded with a corresponding offset to the related regulatory asset.  The assets held in the CYAPC and YAEC spent nuclear fuel trusts

are restricted for settling the ARO and all other nuclear fuel storage obligations.  For further information on the assets held in the spent nuclear fuel trusts, see Note 5, "Marketable Securities," to the financial statements.

The increase in the ARO balance at NSTAR Electric for the year ended December 31, 2019 was due to the recording of a new liability associated with the installation of a 115kV distribution cable across Boston Harbor to Deer Island that was placed into service in 2019. See Note 13F, "Commitments and Contingencies - Eversource and NSTAR Electric Boston Harbor Civil Action," to the financial statements for further information on the HEEC distribution cable.

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EMPLOYEE BENEFITS - Schedule of Estimated Future Benefit Payments (Details) $ in Millions	Dec. 31, 2019 USD ($)
Pension Plan
Defined Contribution Plan Disclosure [Line Items]
2020	$ 320.1
2021	328.7
2022	337.5
2023	346.5
2024	352.4
2025-2029	1,813.1
Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
2020	58.1
2021	57.9
2022	57.3
2023	56.8
2024	56.2
2025-2029	$ 264.7

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EMPLOYEE BENEFITS - Schedule of Defined Contribution Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost recognized	$ 41.6	$ 38.4	$ 34.5
CL&P
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost recognized	5.5	5.0	4.6
NSTAR Electric
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost recognized	10.3	9.7	8.5
PSNH
Defined Contribution Plan Disclosure [Line Items]
Defined contribution plan, cost recognized	$ 3.5	$ 3.3	$ 3.7

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RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

12 Months Ended

Dec. 31, 2019

Rate Reduction Bonds and Variable Interest Entity [Abstract]

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

Rate Reduction Bonds: On May 8, 2018, PSNH Funding, a wholly-owned subsidiary of PSNH, issued $635.7 million of securitized RRBs in multiple tranches with a weighted average interest rate of 3.66 percent, and final maturity dates ranging from 2026 to 2035.  The RRBs are expected to be repaid by February 1, 2033. RRB payments consist of principal and interest and are paid semi-annually, beginning on February 1, 2019. The RRBs were issued pursuant to a finance order issued by the NHPUC on January 30, 2018 to recover remaining costs resulting from the divestiture of PSNH’s generation assets.

The proceeds were used by PSNH Funding to purchase PSNH’s stranded cost asset-recovery property, including its vested property right to bill, collect and adjust a non-bypassable stranded cost recovery charge from PSNH’s retail customers. The collections are used to pay principal, interest and other costs in connection with the RRBs. The RRBs are secured by the stranded cost asset-recovery property. Cash collections from the stranded cost recovery charges and funds on deposit in trust accounts are the sole source of funds to satisfy the debt obligation. PSNH is not the owner of the RRBs, and PSNH Funding’s assets and revenues are not available to pay PSNH’s creditors. The RRBs are non-recourse senior secured obligations of PSNH Funding and are not insured or guaranteed by PSNH or Eversource Energy.

PSNH Funding was formed solely to issue RRBs to finance PSNH’s unrecovered remaining costs associated with the divestiture of its generation assets. PSNH Funding is considered a VIE primarily because the equity capitalization is insufficient to support its operations. PSNH has the power to direct the significant activities of the VIE and is most closely associated with the VIE as compared to other interest holders. Therefore, PSNH is considered the primary beneficiary and consolidates PSNH Funding in its consolidated financial statements. The following tables summarize the impact of PSNH Funding on PSNH's balance sheets and income statements:

(Millions of Dollars)
Balance Sheet:	As of December 31, 2019		As of December 31, 2018
Restricted Cash - Current Portion (included in Current Assets)	$	32.5	$	47.5
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2
Securitized Stranded Cost (included in Regulatory Assets)	565.3		608.4
Other Regulatory Liabilities (included in Regulatory Liabilities)	5.6		5.8
Accrued Interest (included in Other Current Liabilities)	8.6		14.4
Rate Reduction Bonds - Current Portion	43.2		52.3
Rate Reduction Bonds - Long-Term Portion	540.1		583.3

(Millions of Dollars) Income Statement:	For the Year Ended December 31, 2019		For the Year Ended December 31, 2018
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	$	43.0	$	27.3
Interest Expense on RRB Principal (included in Interest Expense)	21.1		14.4

Variable Interest Entities - Other: The Company's variable interests outside of the consolidated group include contracts that are required by regulation and provide for regulatory recovery of contract costs and benefits through customer rates.  Eversource, CL&P and NSTAR Electric hold variable interests in VIEs through agreements with certain entities that own single renewable energy or peaking generation power plants, with other independent power producers and with transmission businesses.  Eversource, CL&P and NSTAR Electric do not control the activities that are economically significant to these VIEs or provide financial or other support to these VIEs.  Therefore, Eversource, CL&P and NSTAR Electric do not consolidate these VIEs.

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SCHEDULE I - FINANCIAL INFORMATION OF REGISTRANT

12 Months Ended

Dec. 31, 2019

Condensed Financial Information Disclosure [Abstract]

SCHEDULE I - FINANCIAL INFORMATION OF REGISTRANT

SCHEDULE I

EVERSOURCE ENERGY (PARENT)

FINANCIAL INFORMATION OF REGISTRANT

BALANCE SHEETS

AS OF DECEMBER 31, 2019 AND 2018

(Thousands of Dollars)

	2019			2018
ASSETS
Current Assets:
Cash	$	1,469		$	591
Accounts Receivable from Subsidiaries	25,070			32,175
Notes Receivable from Subsidiaries	1,376,000			991,400
Prepayments and Other Current Assets	33,546			26,861
Total Current Assets	1,436,085			1,051,027
Deferred Debits and Other Assets:
Investments in Subsidiary Companies, at Equity	13,162,337			12,009,659
Notes Receivable from Subsidiaries	157,000			323,500
Accumulated Deferred Income Taxes	27,578			40,454
Goodwill	3,231,811			3,231,811
Other Long-Term Assets	92,394			73,669
Total Deferred Debits and Other Assets	16,671,120			15,679,093
Total Assets	$	18,107,205		$	16,730,120
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	878,584		$	631,500
Long-Term Debt - Current Portion	23,933			378,883
Accounts Payable to Subsidiaries	4,333			8,432
Other Current Liabilities	62,385			57,877
Total Current Liabilities	969,235			1,076,692
Deferred Credits and Other Liabilities	149,637			134,614
Long-Term Debt	4,358,339			4,031,997
Common Shareholders' Equity:
Common Shares	1,729,292			1,669,392
Capital Surplus, Paid in	7,087,768			6,241,222
Retained Earnings	4,177,048			3,953,974
Accumulated Other Comprehensive Loss	(65,059		)	(60,000		)
Treasury Stock	(299,055		)	(317,771		)
Common Shareholders' Equity	12,629,994			11,486,817
Total Liabilities and Capitalization	$	18,107,205		$	16,730,120

See the Combined Notes to Financial Statements in this Annual Report on Form 10-K for a description of significant accounting matters related to Eversource parent, including Eversource common shares information as described in Note 19, "Common Shares," material obligations and guarantees as described in Note 13, "Commitments and Contingencies," and debt agreements as described in Note 8, "Short-Term Debt," and Note 9, "Long-Term Debt."

SCHEDULE I

EVERSOURCE ENERGY (PARENT)

FINANCIAL INFORMATION OF REGISTRANT

STATEMENTS OF INCOME

FOR THE YEARS ENDED DECEMBER 31, 2019, 2018 AND 2017

(Thousands of Dollars, Except Share Information)

	2019			2018			2017
Operating Revenues	$	—		$	—		$	—
Operating Expenses:
Other	50,100			(6,552		)	(32,189		)
Operating (Loss)/Income	(50,100		)	6,552			32,189
Interest Expense	163,937			123,638			80,700
Other Income, Net:
Equity in Earnings of Subsidiaries	1,001,526			1,049,748			993,063
Other, Net	68,137			47,581			23,339
Other Income, Net	1,069,663			1,097,329			1,016,402
Income Before Income Tax Benefit	855,626			980,243			967,891
Income Tax Benefit	(53,427		)	(52,757		)	(20,105		)
Net Income	$	909,053		$	1,033,000		$	987,996
Basic Earnings per Common Share	$	2.83		$	3.25		$	3.11
Diluted Earnings per Common Share	$	2.81		$	3.25		$	3.11
Weighted Average Common Shares Outstanding:
Basic	321,416,086			317,370,369			317,411,097
Diluted	322,941,636			317,993,934			318,031,580

STATEMENTS OF COMPREHENSIVE INCOME

	2019			2018			2017
Net Income	$	909,053		$	1,033,000		$	987,996
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	1,393			1,756			1,974
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,166			(547		)	(350		)
Change in Funded Status of Pension, SERP and PBOP Benefit Plans	(7,618		)	5,194			(2,745		)
Other Comprehensive (Loss)/Income, Net of Tax	(5,059		)	6,403			(1,121		)
Comprehensive Income	$	903,994		$	1,039,403		$	986,875

See the Combined Notes to Financial Statements in this Annual Report on Form 10-K for a description of significant accounting matters related to Eversource parent, including Eversource common shares information as described in Note 19, "Common Shares," material obligations and guarantees as described in Note 13, "Commitments and Contingencies," and debt agreements as described in Note 8, "Short-Term Debt," and Note 9, "Long-Term Debt."

SCHEDULE I

EVERSOURCE ENERGY (PARENT)

FINANCIAL INFORMATION OF REGISTRANT

STATEMENTS OF CASH FLOWS

FOR THE YEARS ENDED DECEMBER 31, 2019, 2018 and 2017

(Thousands of Dollars)

	2019			2018			2017
Operating Activities:
Net Income	$	909,053		$	1,033,000		$	987,996
Adjustments to Reconcile Net Income to Net Cash
Flows Provided by Operating Activities:
Equity in Earnings of Subsidiaries	(1,001,526		)	(1,049,748		)	(993,063		)
Cash Dividends Received from Subsidiaries	883,000			569,500			753,300
Deferred Income Taxes	13,382			20,032			37,867
Other	19,584			(31,093		)	(36,052		)
Changes in Current Assets and Liabilities:
Accounts Receivables from Subsidiaries	7,105			(28,716		)	29,405
Taxes Receivable/Accrued, Net	(605		)	(20,207		)	1,555
Accounts Payable to Subsidiaries	(4,099		)	(9,817		)	9,763
Other Current Assets and Liabilities, Net	(2,503		)	2,553			7,536
Net Cash Flows Provided by Operating Activities	823,391			485,504			798,307
Investing Activities:
Capital Contributions to Subsidiaries	(1,039,000		)	(955,700		)	(1,156,731		)
Return of Capital from Subsidiary	—			530,000			—
Increase in Notes Receivable from Subsidiaries	(218,100		)	(158,210		)	(192,100		)
Other Investing Activities	(1,799		)	(1,149		)	1,484
Net Cash Flows Used in Investing Activities	(1,258,899		)	(585,059		)	(1,347,347		)
Financing Activities:
Issuance of Common Shares, Net of Issuance Costs	852,254			—			—
Cash Dividends on Common Shares	(663,239		)	(640,110		)	(602,083		)
Issuance of Long-Term Debt	—			1,550,000			1,200,000
Retirement of Long-Term Debt	(350,000		)	(450,000		)	—
Increase/(Decrease) in Notes Payable	593,370			(347,810		)	(42,690		)
Other Financing Activities	4,001			(12,455		)	(5,759		)
Net Cash Flows Provided by Financing Activities	436,386			99,625			549,468
Net Increase in Cash	878			70			428
Cash - Beginning of Year	591			521			93
Cash - End of Year	$	1,469		$	591		$	521
Supplemental Cash Flow Information:
Cash Paid/(Received) During the Year for:
Interest	$	161,323		$	118,533		$	73,868
Income Taxes	$	(63,227	)	$	(30,239	)	$	(59,526	)

See the Combined Notes to Financial Statements in this Annual Report on Form 10-K for a description of significant accounting matters related to Eversource parent, including Eversource common shares information as described in Note 19, "Common Shares," material obligations and guarantees as described in Note 13, "Commitments and Contingencies," and debt agreements as described in Note 8, "Short-Term Debt," and Note 9, "Long-Term Debt."

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COMMITMENTS AND CONTINGENCIES - Schedule of Total Costs Incurred (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Long-term Purchase Commitment [Line Items]
Renewable Energy	$ 320.8	$ 218.5	$ 235.5
Purchased Power and Capacity	62.1	72.0	103.9
Peaker CfDs		20.9	38.7
Natural Gas Procurement	448.5	432.4	377.0
Transmission Support Commitments	21.8	23.4	19.8
Coal, Wood and Other	0.0	0.0	47.7
CL&P
Long-term Purchase Commitment [Line Items]
Renewable Energy	160.6	63.2	51.0
Purchased Power and Capacity	50.4	49.4	81.0
Peaker CfDs		20.9	38.7
Transmission Support Commitments	8.6	9.2	7.8
Coal, Wood and Other	0.0	0.0	0.0
NSTAR Electric
Long-term Purchase Commitment [Line Items]
Renewable Energy	89.9	89.8	123.7
Purchased Power and Capacity	5.1	4.4	4.0
Peaker CfDs	0.0	0.0	0.0
Transmission Support Commitments	8.6	9.2	7.8
Coal, Wood and Other	0.0	0.0	0.0
PSNH
Long-term Purchase Commitment [Line Items]
Renewable Energy	70.3	65.5	60.8
Purchased Power and Capacity	6.6	18.2	18.9
Peaker CfDs	0.0	0.0	0.0
Transmission Support Commitments	4.6	5.0	4.2
Coal, Wood and Other	$ 0.0	$ 0.0	$ 47.7

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COMMITMENTS AND CONTINGENCIES - Schedule of Number of Sites and Reserves (Details) - site	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Loss Contingencies [Line Items]
Number of Sites	57	60
CL&P
Loss Contingencies [Line Items]
Number of Sites	15	15
NSTAR Electric
Loss Contingencies [Line Items]
Number of Sites	15	16
PSNH
Loss Contingencies [Line Items]
Number of Sites	9	9

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Net Income	$ 916,572	$ 1,040,519	$ 995,515
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	1,393	1,756	1,974
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,166	(547)	(350)
Change in Funded Status of Pension, SERP and PBOP Benefit Plans	(7,618)	5,194	(2,745)
Other Comprehensive (Loss)/Income, Net of Tax	(5,059)	6,403	(1,121)
Comprehensive Income Attributable to Noncontrolling Interests	(7,519)	(7,519)	(7,519)
Comprehensive Income Attributable to Common Shareholders	903,994	1,039,403	986,875
The Connecticut Light and Power Company
Net Income	410,852	377,717	376,726
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	(26)	51	334
Changes in Unrealized Gains/(Losses) on Marketable Securities	41	(19)	(12)
Other Comprehensive (Loss)/Income, Net of Tax	15	32	322
Comprehensive Income Attributable to Common Shareholders	410,867	377,749	377,048
NSTAR Electric Company
Net Income	431,956	383,090	374,726
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	437	437	438
Changes in Unrealized Gains/(Losses) on Marketable Securities	12	(5)	(3)
Change in Funded Status of Pension, SERP and PBOP Benefit Plans	1,084	13	(264)
Other Comprehensive (Loss)/Income, Net of Tax	1,533	445	171
Comprehensive Income Attributable to Common Shareholders	433,489	383,535	374,897
Public Service Company of New Hampshire
Net Income	134,048	115,876	135,996
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	1,075	1,104	1,162
Changes in Unrealized Gains/(Losses) on Marketable Securities	69	(33)	(21)
Other Comprehensive (Loss)/Income, Net of Tax	1,144	1,071	1,141
Comprehensive Income Attributable to Common Shareholders	$ 135,192	$ 116,947	$ 137,137

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REVENUES

12 Months Ended

Dec. 31, 2019

Revenue from Contract with Customer [Abstract]

REVENUES

REVENUES

On January 1, 2018, Eversource, including CL&P, NSTAR Electric and PSNH, adopted ASU 2014-09, “Revenue from Contracts with Customers (Topic 606)” using the modified retrospective approach. The core principle of this accounting guidance is that revenue is recognized when promised goods or services (referred to as performance obligations) are transferred to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. A five-step model is used for recognizing and measuring revenue from contracts with customers, which includes identifying the contract with the customer, identifying the performance obligations promised within the contract, determining the transaction price (the amount of consideration to which the company expects to be entitled), allocating the transaction price to the performance obligations and recognizing revenue when (or as) the performance obligation is satisfied.

The following table presents operating revenues disaggregated by revenue source:

	For the Year Ended December 31, 2019
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution			Electric Transmission		Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	3,723.7	$	555.1		$	—	$	132.3		$	—	$	—		$	4,411.1
Commercial	2,584.8		347.6			—		63.9			—		(4.3		)	2,992.0
Industrial	331.8		96.9			—		4.5			—		(11.6		)	421.6
Total Retail Tariff Sales Revenues	6,640.3		999.6			—		200.7			—		(15.9		)	7,824.7
Wholesale Transmission Revenues	—		—			1,293.3		—			61.3		(1,085.2		)	269.4
Wholesale Market Sales Revenues	215.7		55.4			—		4.1			—		—			275.2
Other Revenues from Contracts with Customers	54.8		2.8			13.2		7.0			967.2		(969.0		)	76.0
Reserve for Revenues Subject to Refund	1.3		6.2			—		(2.8		)	—		—			4.7
Total Revenues from Contracts with Customers	6,912.1		1,064.0			1,306.5		209.0			1,028.5		(2,070.1		)	8,450.0
Alternative Revenue Programs	45.9		(4.9		)	81.8		4.6			—		(74.2		)	53.2
Other Revenues	18.5		3.1			0.7		1.0			—		—			23.3
Total Operating Revenues	$	6,976.5	$	1,062.2		$	1,389.0	$	214.6		$	1,028.5	$	(2,144.3	)	$	8,526.5

	For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	3,766.6		$	542.5		$	—		$	130.7		$	—	$	—		$	4,439.8
Commercial	2,634.7			334.8			—			63.3			—		(4.5		)	3,028.3
Industrial	351.9			96.0			—			4.4			—		(10.0		)	442.3
Total Retail Tariff Sales Revenues	6,753.2			973.3			—			198.4			—		(14.5		)	7,910.4
Wholesale Transmission Revenues	—			—			1,308.9			—			47.3		(1,092.2		)	264.0
Wholesale Market Sales Revenues	179.5			57.5			—			4.1			—		—			241.1
Other Revenues from Contracts with Customers	65.9			(2.2		)	12.6			7.2			889.0		(891.0		)	81.5
Reserve for Revenues Subject to Refund	(12.3		)	(8.3		)	—			(3.7		)	—		—			(24.3		)
Total Revenues from Contracts with Customers	6,986.3			1,020.3			1,321.5			206.0			936.3		(1,997.7		)	8,472.7
Alternative Revenue Programs	(47.0		)	(1.2		)	(35.2		)	5.4			—		31.9			(46.1		)
Other Revenues	17.9			3.1			—			0.6			—		—			21.6
Total Operating Revenues	$	6,957.2		$	1,022.2		$	1,286.3		$	212.0		$	936.3	$	(1,965.8	)	$	8,448.2

	For the Years Ended December 31,
	2019									2018
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	1,837.1		$	1,322.1		$	564.5		$	1,828.2		$	1,380.9		$	557.5
Commercial	922.9			1,349.4			314.6			928.1			1,391.5			316.9
Industrial	138.3			115.8			77.7			147.7			124.9			79.3
Total Retail Tariff Sales Revenues	2,898.3			2,787.3			956.8			2,904.0			2,897.3			953.7
Wholesale Transmission Revenues	587.1			517.3			188.9			620.6			488.8			199.5
Wholesale Market Sales Revenues	105.1			73.1			37.5			48.3			76.1			56.6
Other Revenues from Contracts with Customers	36.4			18.7			15.6			35.0			28.9			15.5
Reserve for Revenues Subject to Refund	—			—			1.3			—			—			(12.3		)
Total Revenues from Contracts with Customers	3,626.9			3,396.4			1,200.1			3,607.9			3,491.1			1,213.0
Alternative Revenue Programs	77.5			41.6			8.6			(65.9		)	0.9			(17.3		)
Other Revenues	10.3			7.0			1.9			8.5			8.3			1.1
Eliminations	(482.1		)	(400.4		)	(144.7		)	(454.3		)	(387.4		)	(149.2		)
Total Operating Revenues	$	3,232.6		$	3,044.6		$	1,065.9		$	3,096.2		$	3,112.9		$	1,047.6

Retail Tariff Sales: Regulated utilities provide products and services to their regulated customers under rates, pricing, payment terms and conditions of service, regulated by each state regulatory agency. The arrangement whereby a utility provides commodity service to a customer for a price approved by the respective state regulatory commission is referred to as a tariff sale contract, and the tariff governs all aspects of the provision of regulated services by utilities. The majority of revenue for Eversource, CL&P, NSTAR Electric and PSNH is derived from regulated retail tariff sales for the sale and distribution of electricity, natural gas and water to residential, commercial and industrial retail customers.

The utility's performance obligation for the regulated tariff sales is to provide electricity, natural gas or water to the customer as demanded. The promise to provide the commodity represents a single performance obligation, as it is a promise to transfer a series of distinct goods or services that are substantially the same and that have the same pattern of transfer to the customer. Revenue is recognized over time as the customer simultaneously receives and consumes the benefits provided by the utility, and the utility satisfies its performance obligation. Revenue is recognized based on the output method as there is a directly observable output to the customer (electricity, natural gas or water units delivered to the customer and immediately consumed). Each Eversource utility is entitled to be compensated for performance completed to date (service taken by the customer) until service is terminated.

In regulated tariff sales, the transaction prices are the rates approved by the respective state regulatory commissions.  In general, rates can only be changed through formal proceedings with the state regulatory commissions. These rates are designed to recover the costs to provide service to customers and include a return on investment. Regulatory commission-approved tracking mechanisms are included in these rates and are also used to recover, on a fully-reconciling basis, certain costs, such as the procurement of energy supply, retail transmission charges, energy efficiency program costs, net metering for distributed generation, and restructuring and stranded costs. These tracking mechanisms result in rates being changed periodically to ensure recovery of actual costs incurred.

Customers may elect to purchase electricity from each Eversource electric utility or may contract separately with a competitive third party supplier. Revenue is not recorded for the sale of the electricity commodity to customers who have contracted separately with these suppliers, only the delivery to a customer, as the utility is acting as an agent on behalf of the third party supplier.

Wholesale Transmission Revenues:  The Eversource electric transmission-owning companies (CL&P, NSTAR Electric and PSNH) each own and maintain transmission facilities that are part of an interstate power transmission grid over which electricity is transmitted throughout New England. CL&P, NSTAR Electric and PSNH, as well as most other New England utilities, are parties to a series of agreements that provide for coordinated planning and operation of the region's transmission facilities and the rules by which they acquire transmission services.  The Eversource electric transmission-owning companies have a combination of FERC-approved regional and local formula rates that work in tandem to recover all their transmission costs. These rates are part of the ISO-NE Tariff. Regional rates recover the costs of higher voltage transmission facilities that benefit the region and are collected from all New England transmission customers, including the Eversource distribution businesses. Eversource's local rates recover the companies' total transmission revenue requirements, less revenues received from regional rates and other sources, and are collected from Eversource's distribution businesses and other transmission customers. The distribution businesses of Eversource, in turn, recover the FERC approved charges from retail customers through annual or semiannual tracking mechanisms, which are retail tariff sales.

The utility's performance obligation for regulated wholesale transmission sales is to provide transmission services to the customer as demanded. The promise to provide transmission service represents a single performance obligation. The transaction prices are the transmission rate formulas as defined by the ISO-NE Tariff and are regulated and established by FERC. Wholesale transmission revenue is recognized over time as the performance obligation is completed, which occurs as transmission services are provided to customers. The revenue is recognized based on the output method. Each Eversource utility is entitled to be compensated for performance completed to date (e.g., use of the transmission system by the customer).

Wholesale Market Sales Revenues: Wholesale market sales transactions include sales of energy and energy-related products into the ISO-NE wholesale electricity market, sales of natural gas to third party marketers, and also the sale of RECs to various counterparties. ISO-NE oversees the region's wholesale electricity market and administers the transactions and terms and conditions, including payment terms, which are established in the ISO-NE tariff, between the buyers and sellers in the market. Pricing is set by the wholesale market. The wholesale transactions in the ISO-NE market occur on a day-ahead basis or a real-time basis (daily) and are, therefore, short-term. Transactions are tracked and reported by ISO-NE net by the hour, which is the net hourly position of energy sales and purchases by each market participant. Beginning in the first quarter of 2018, the performance obligation for ISO-NE energy transactions is defined to be the net by hour transaction. Revenue is recognized when the performance obligation for these energy sales transactions is satisfied, when the sale occurs and the energy is transferred to the customer. For sales of natural gas, transportation, and natural gas pipeline capacity to third party marketers, revenue is recognized when the performance obligation is satisfied at the point in time the sale occurs and the natural gas or related product is transferred to the marketer. RECs are sold to various counterparties, and revenue is recognized when the performance obligation is satisfied upon transfer of title to the customer through the New England Power Pool Generation Information System.

Other Revenues from Contracts with Customers: Other revenues from contracts with customers primarily include property rentals that are not deemed leases. These revenues are generally recognized on a straight-line basis over time as the service is provided to the customer. Other revenues also include revenues from Eversource's service company, which is eliminated in consolidation.

Reserve for Revenues Subject to Refund: Current base rates include an estimate of income taxes, which was based on the U.S. federal corporate income tax rate in effect at the time of the rate proceeding. Eversource established a regulatory liability, recorded as a reduction to revenue, to reflect the difference between the 35 percent federal corporate income tax rate included in rates charged to customers and the 21 percent federal corporate income tax rate, effective January 1, 2018 as a result of the Tax Cuts and Jobs Act, until rates billed to customers reflect the lower federal tax rate. Effective May 1, 2018, CL&P adjusted distribution rates billed to customers to reflect the lower federal income tax rate prospectively and, as of December 31, 2018, fully refunded its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through April 30, 2018. Effective November 15, 2018, Yankee Gas adjusted distribution rates to reflect the lower federal income tax rate prospectively and to refund its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through November 14, 2018. Effective July 1, 2019, PSNH adjusted temporary distribution rates to reflect the lower federal income tax rate prospectively and to refund its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through June 30, 2019. For NSTAR Electric and NSTAR Gas, a December 2018 DPU order indicated that the DPU would not require a revision to base distribution rates for any potential refunds associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 to the effective dates of each company's rate changes (effective February 1, 2018 for NSTAR Electric and July 1, 2018 for NSTAR Gas).

Alternative Revenue Programs: In accordance with accounting guidance for rate-regulated operations, certain of Eversource's utilities' rate making mechanisms qualify as alternative revenue programs (ARPs) if they meet specified criteria, in which case revenues may be recognized prior to billing based on allowed levels of collection in rates. Eversource's utility companies recognize revenue and record a regulatory asset or liability once the condition or event allowing for the automatic adjustment of future rates occurs. ARP revenues include both the recognition of the deferral adjustment to ARP revenues, when the regulator-specified condition or event allowing for additional billing or refund has occurred, and an equal and offsetting reversal of the ARP deferral to revenues as those amounts are reflected in the price of service in subsequent periods.

Eversource’s ARPs include the revenue decoupling mechanism and the annual reconciliation adjustment to transmission formula rates, described below.

• Certain Eversource electric, natural gas and water companies, including CL&P and NSTAR Electric, have revenue decoupling mechanisms approved by a regulatory commission (decoupled companies). Decoupled companies’ distribution revenues are not directly based on sales volumes. The decoupled companies reconcile their annual base distribution rate recovery to pre-established levels of baseline distribution delivery service revenues, with any difference between the allowed level of distribution revenue and the actual amount realized adjusted through subsequent rates.

• The transmission formula rates provide for the annual reconciliation and recovery or refund of estimated costs to actual costs.  The financial impacts of differences between actual and estimated costs are deferred for future recovery from, or refund to, transmission customers.  This transmission deferral reconciles billed transmission revenues to the revenue requirement for our transmission businesses.

Other Revenues: Other Revenues include certain fees charged to customers that are not considered revenue from contracts with customers and lease revenues under lessor accounting guidance. Lease revenues totaled $4.4 million at Eversource, $1.0 million at CL&P, and $2.7 million at NSTAR Electric for the year ended December 31, 2019.

Intercompany Eliminations: Intercompany eliminations are primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business, and revenues from Eversource's service company. Intercompany revenues and expenses between the Eversource wholesale transmission businesses and the Eversource distribution businesses and from Eversource's service company are eliminated in consolidation and included in "Eliminations" in the table above.

Receivables: Receivables, Net on the balance sheet include trade receivables from our retail customers and receivables arising from ISO-NE billing related to wholesale transmission contracts and wholesale market transactions, sales of natural gas and capacity to marketers, sales of RECs, and property rentals. In general, retail tariff customers and wholesale transmission customers are billed monthly and the payment terms are generally due and payable upon receipt of the bill.

Unbilled Revenues: Unbilled Revenues on the balance sheet represent estimated amounts due from retail customers for electricity, natural gas or water delivered to customers but not yet billed. The utility company has satisfied its performance obligation and the customer has received and consumed the commodity as of the balance sheet date, and therefore, the utility company records revenue for those services in the period the services were provided. Only the passage of time is required before the company is entitled to payment for the satisfaction of the performance obligation. Payment from customers is due monthly as services are rendered and amounts are billed. Actual amounts billed to customers when meter readings become available may vary from the estimated amount.

Unbilled revenues are recognized by allocating estimated unbilled sales volumes to the respective customer classes, and then applying an estimated rate by customer class to those sales volumes. Unbilled revenue estimates reflect seasonality, weather, customer usage patterns, customer rates in effect for customer classes, and the timing of customer billing. The companies that have a decoupling mechanism record a regulatory deferral to reflect the actual allowed amount of revenue associated with their respective decoupled distribution rate design.

Practical Expedients: Eversource has elected practical expedients in the accounting guidance that allow the company to record revenue in the amount that the company has a right to invoice, if that amount corresponds directly with the value to the customer of the company's performance to date, and not to disclose related unsatisfied performance obligations. Retail and wholesale transmission tariff sales fall into this category, as these sales are recognized as revenue in the period the utility provides the service and completes the performance obligation, which is the same as the monthly amount billed to customers. There are no other material revenue streams for which Eversource has unsatisfied performance obligations.

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COMMITMENTS AND CONTINGENCIES - FERC ROE Complaints (Details) $ in Millions				12 Months Ended	30 Months Ended	36 Months Ended
	Oct. 16, 2018	Oct. 06, 2017	Apr. 29, 2016	Dec. 31, 2019 USD ($)	Apr. 14, 2017	Oct. 15, 2014	Apr. 26, 2016 complaint	Jul. 31, 2014 complaint
Loss Contingencies [Line Items]
Percentage of base ROE reasonably justified	10.41%
Percentage of incentive cap on total ROE	13.08%
FERC ROE Complaints
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number | complaint							4
Period of complaint				15 months
Basis point change				0.01%
Estimate of possible loss for each 10 basis point change to base ROE				$ 3.0
FERC ROE First, Second and Third Complaints
Loss Contingencies [Line Items]
Loss Contingency, Pending Claims, Number | complaint								3
Base ROE percentage challenged by complainants				11.14%
Percentage of ROE for any incentive project	13.08%
FERC ROE First Complaint
Loss Contingencies [Line Items]
Percentage of ROE for any incentive project					11.74%
Refund payments				$ 38.9
FERC ROE Second Complaint
Loss Contingencies [Line Items]
Percentage of base ROE of complaint period				10.57%	10.57%
Percentage of ROE for any incentive project				11.74%
Loss contingency, estimate of possible earnings impact				$ 39.1
FERC ROE Fourth Complaint
Loss Contingencies [Line Items]
Percentage of base ROE of complaint period			10.57%
Maximum percentage cap of ROE for incentive projects			11.74%
Percentage of ROE for any incentive project		10.57%
Original base ROE authorized by FERC at time of complaint		11.74%
CL&P | FERC ROE First Complaint
Loss Contingencies [Line Items]
Refund payments				22.4
CL&P | FERC ROE Second Complaint
Loss Contingencies [Line Items]
Loss contingency, estimate of possible earnings impact				21.4
NSTAR Electric | FERC ROE First Complaint
Loss Contingencies [Line Items]
Refund payments				13.7
NSTAR Electric | FERC ROE Second Complaint
Loss Contingencies [Line Items]
Loss contingency, estimate of possible earnings impact				14.6
PSNH | FERC ROE First Complaint
Loss Contingencies [Line Items]
Refund payments				2.8
PSNH | FERC ROE Second Complaint
Loss Contingencies [Line Items]
Loss contingency, estimate of possible earnings impact				$ 3.1
Minimum | FERC ROE First, Second and Third Complaints
Loss Contingencies [Line Items]
Percentage of ROE for any incentive project						11.14%
Maximum | FERC ROE First, Second and Third Complaints
Loss Contingencies [Line Items]
Percentage of ROE for any incentive project						13.10%

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REGULATORY ACCOUNTING (Tables)

12 Months Ended

Dec. 31, 2019

Regulated Operations [Abstract]

Components of Regulatory Assets

The components of regulatory assets were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Benefit Costs	$	2,382.9	$	539.0	$	629.8	$	218.2	$	1,914.8	$	424.7	$	544.4	$	169.6
Income Taxes, Net	725.8		458.8		108.0		12.8		728.6		454.4		105.9		8.3
Securitized Stranded Costs	565.3		—		—		565.3		608.4		—		—		608.4
Storm Restoration Costs, Net	540.6		274.6		200.6		65.4		576.0		302.6		212.9		60.5
Regulatory Tracker Mechanisms	411.5		78.3		207.1		65.8		316.0		33.2		169.1		67.3
Derivative Liabilities	334.5		329.2		—		—		356.5		356.5		—		—
Goodwill-related	331.5		—		284.6		—		348.4		—		299.1		—
Asset Retirement Obligations	97.2		30.8		50.3		3.6		89.2		32.3		42.2		3.3
Other Regulatory Assets	125.4		25.2		55.2		14.7		208.0		27.0		64.6		12.1
Total Regulatory Assets	5,514.7		1,735.9		1,535.6		945.8		5,145.9		1,630.7		1,438.2		929.5
Less:  Current Portion	651.1		178.6		285.6		84.1		514.8		125.2		241.7		67.2
Total Long-Term Regulatory Assets	$	4,863.6	$	1,557.3	$	1,250.0	$	861.7	$	4,631.1	$	1,505.5	$	1,196.5	$	862.3

Components of Regulatory Liabilities

 The components of regulatory liabilities were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
EDIT due to Tax Cuts and Jobs Act	$	2,844.6	$	1,022.8	$	1,071.2	$	392.8	$	2,883.0	$	1,031.0	$	1,103.7	$	396.4
Cost of Removal	559.8		64.6		330.6		16.3		521.0		39.9		307.1		22.1
Benefit Costs	84.5		—		72.2		—		91.2		—		76.9		—
Regulatory Tracker Mechanisms	325.1		94.8		165.6		57.0		309.0		89.5		163.7		48.3
AFUDC - Transmission	73.2		46.0		27.2		—		70.7		47.4		23.3		—
Revenue Subject to Refund due to Tax Cuts   and Jobs Act	14.6		—		—		6.0		24.6		—		—		12.6
Other Regulatory Liabilities	117.4		19.6		59.0		7.1		80.2		24.0		29.2		4.2
Total Regulatory Liabilities	4,019.2		1,247.8		1,725.8		479.2		3,979.7		1,231.8		1,703.9		483.6
Less:  Current Portion	361.2		82.8		209.2		65.8		370.2		109.6		190.6		55.5
Total Long-Term Regulatory Liabilities	$	3,658.0	$	1,165.0	$	1,516.6	$	413.4	$	3,609.5	$	1,122.2	$	1,513.3	$	428.1

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

12 Months Ended

Dec. 31, 2019

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

A.     About Eversource, CL&P, NSTAR Electric and PSNH

Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business.  Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), Yankee Gas and NSTAR Gas (natural gas utilities) and Aquarion (water utilities).  Eversource provides energy delivery and/or water service to approximately four million electric, natural gas and water customers through eight regulated utilities in Connecticut, Massachusetts and New Hampshire.  

Eversource, CL&P, NSTAR Electric and PSNH are reporting companies under the Securities Exchange Act of 1934.  Eversource Energy is a public utility holding company under the Public Utility Holding Company Act of 2005.  Arrangements among the regulated electric companies and other Eversource companies, outside agencies and other utilities covering interconnections, interchange of electric power and sales of utility property are subject to regulation by the FERC. Eversource's regulated companies are subject to regulation of rates, accounting and other matters by the FERC and/or applicable state regulatory commissions (the PURA for CL&P, Yankee Gas and Aquarion, the DPU for NSTAR Electric, NSTAR Gas and Aquarion, and the NHPUC for PSNH and Aquarion).

CL&P, NSTAR Electric and PSNH furnish franchised retail electric service in Connecticut, Massachusetts and New Hampshire.  Yankee Gas and NSTAR Gas are engaged in the distribution and sale of natural gas to customers within Connecticut and Massachusetts, respectively.  Aquarion is engaged in the collection, treatment and distribution of water in Connecticut, Massachusetts and New Hampshire. CL&P, NSTAR Electric and PSNH's results include the operations of their respective distribution and transmission businesses. The distribution business also includes the results of NSTAR Electric's solar power facilities and PSNH's generation facilities prior to sale in 2018. PSNH completed the sales of all its thermal and hydroelectric generation assets in 2018. See Note 14, "Generation Asset Sale," for further information.

Eversource Service, Eversource's service company, and several wholly-owned real estate subsidiaries of Eversource, provide support services to Eversource, including its regulated companies.

B.     Basis of Presentation

The consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries. Intercompany transactions have been eliminated in consolidation.  The accompanying consolidated financial statements of Eversource, NSTAR Electric and PSNH and the financial statements of CL&P are herein collectively referred to as the "financial statements."  

The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent liabilities as of 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.

Eversource consolidates the operations of CYAPC and YAEC, both of which are inactive regional nuclear generation companies engaged in the long-term storage of their spent nuclear fuel. Eversource consolidates CYAPC and YAEC because CL&P's, NSTAR Electric's and PSNH's combined ownership and voting interests in each of these entities is greater than 50 percent.  Intercompany transactions between CL&P, NSTAR Electric, PSNH and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.  

Eversource's consolidated financial information includes the results of Aquarion and its subsidiaries beginning from the date of the acquisition on December 4, 2017.

Eversource holds several equity ownership interests that are not consolidated and are accounted for under the equity method.

In accordance with accounting guidance on noncontrolling interests in consolidated financial statements, the Preferred Stock of CL&P and the Preferred Stock of NSTAR Electric, which are not owned by Eversource or its consolidated subsidiaries and are not subject to mandatory redemption, have been presented as noncontrolling interests in the financial statements of Eversource.  The Preferred Stock of CL&P and the Preferred Stock of NSTAR Electric are considered to be temporary equity and have been classified between liabilities and permanent shareholders' equity on the balance sheets of Eversource, CL&P and NSTAR Electric due to a provision in the preferred stock agreements of both CL&P and NSTAR Electric that grant preferred stockholders the right to elect a majority of the CL&P and NSTAR Electric Boards of Directors, respectively, should certain conditions exist, such as if preferred dividends are in arrears for a specified amount of time.  The Net Income reported in the statements of income and cash flows represents net income prior to apportionment to noncontrolling interests, which is represented by dividends on preferred stock of CL&P and NSTAR Electric.

Eversource's utility subsidiaries' electric, natural gas and water distribution and transmission businesses are subject to rate-regulation that is based on cost recovery and meets the criteria for application of accounting guidance for entities with rate-regulated operations, which considers the effect of regulation on the differences in the timing of the recognition of certain revenues and expenses from those of other businesses and industries.  See Note 2, "Regulatory Accounting," for further information.

Certain reclassifications of prior year data were made in the accompanying financial statements to conform to the current year presentation.

The Eversource and PSNH 2018 statements of cash flows, the 2018 supplemental cash flow information footnote, and the 2018 segment footnote were revised to correct an error in the presentation of non-cash capital additions.  The impact of this revision on the statement of cash flows is an increase to operating cash inflows in Accounts Payable of $46.6 million and a corresponding increase to investing cash outflows in Investments in Property, Plant and Equipment for the year ended December 31, 2018.  This revision is not deemed material, individually or in the aggregate, to the previously issued financial statements.

As of both December 31, 2019 and 2018, Eversource's carrying amount of goodwill was $4.43 billion. Eversource performs an assessment for possible impairment of its goodwill at least annually.  Eversource completed its annual goodwill impairment test for each of its reporting units as of October 1, 2019 and determined that no impairment exists.  See Note 25B, "Acquisition of Aquarion and Goodwill - Goodwill," for further information.

C.     Accounting Standards

Accounting Standards Issued but Not Yet Effective: In June 2016, the FASB issued Accounting Standards Update (“ASU”) 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides a new model for recognizing credit losses on financial instruments based on an estimate of current expected credit losses. Under the new guidance, immediate recognition of credit losses expected over the life of a financial instrument is required. The standard is effective January 1, 2020. The Company assessed the impacts of this standard on the accounting for credit losses on its financial instruments, including accounts receivable, and does not expect a material impact on the financial statements of Eversource, CL&P, NSTAR Electric or PSNH.

In December 2019, the FASB issued ASU 2019-12, Income Taxes (Topic 740) - Simplifying the Accounting for Income Taxes, which eliminates certain exceptions to the general principles of current income tax guidance in ASC 740, Income Taxes, and simplifies and improves consistency in application of that income tax guidance through clarifications of, and amendments to, ASC 740. The guidance is effective in the first quarter of 2021.  The Company is evaluating the impact of this standard on the financial statements of Eversource, CL&P, NSTAR Electric and PSNH.

Accounting Standards Recently Adopted: On January 1, 2019, the Company adopted ASU 2016-02, Leases (Topic 842), which amended existing lease accounting guidance. The Company applied the Topic 842 lease criteria to new leases and lease renewals entered into effective on or after January 1, 2019.  The ASU required balance sheet recognition of leases deemed to be operating leases as well as additional disclosure requirements.  The recognition, measurement and presentation of expenses and cash flows were not significantly changed.

The Company utilized the modified retrospective transition method allowed in ASU 2018-11, Leases (Topic 842) - Targeted Improvements, which allowed the Company to adopt the new leases standard as of January 1, 2019, with prior periods presented in the financial statements continuing to follow existing lease accounting guidance under Topic 840 (Leases) in the accounting literature.  Implementation of ASU 2018-11 had no effect on retained earnings, and the requirements of the new lease standard (Topic 842) are reflected in the 2019 financial statements and footnotes.

The Company elected the practical expedient package whereby it did not need to reassess whether or not an existing contract is or contains a lease or whether a lease is an operating or capital lease, and it did not need to reassess initial direct costs for leases. Election of this practical expedient allowed us to carry forward our historical lease classifications. The Company elected the practical expedient to not reevaluate land easements existing at adoption if they were not previously accounted for as leases. The Company also elected to use the discount rate as of the January 1, 2019 implementation date to discount its operating lease liabilities. The Company did not elect the hindsight practical expedient to determine the lease term for existing leases.

The Company determined the impact the ASUs had on its financial statements by reviewing its lease population and identifying lease data needed for the disclosure requirements. The Company implemented a new lease accounting system in 2019 to ensure ongoing compliance with the ASU’s requirements. Adoption of the new standard resulted in the recording of operating lease liabilities and right-of-use assets on the balance sheet upon transition at January 1, 2019 of $58.0 million at Eversource, $25.3 million at NSTAR Electric, $0.6 million at CL&P, and $0.6 million at PSNH. Implementation of the new guidance did not have an impact on each company’s results of operations or cash flows.

D.     Impairment of Northern Pass Transmission

Northern Pass was Eversource's planned 1,090 MW HVDC transmission line that would have interconnected from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. As a result of a final decision received on July 19, 2019 from the New Hampshire Supreme Court, whereby the court denied Northern Pass’ appeal and affirmed the NHSEC’s denial of Northern Pass’ siting application on NPT, Eversource concluded that construction of NPT was no longer probable and that there was no constructive path forward for the project. Eversource terminated the project and permanently abandoned any further development.  As a result, substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired.

Based on the conclusion that the construction of Northern Pass was no longer probable, Eversource recorded an impairment charge in 2019 for all of the project costs associated with Northern Pass, which were primarily engineering design, siting, permitting and legal costs, along with appropriate allowances for funds used during construction, and recognized a receivable for certain cost reimbursement agreements. Additionally, Eversource recorded an impairment charge associated with the land acquired to construct Northern Pass in order to recognize the land at its estimated fair value based on assessed values and transaction costs. In total, this resulted in a pre-tax impairment charge of $239.6 million within Operating Income on the statement of income for the year ended December 31, 2019, and was reflected in the Electric Transmission segment. The after-tax impact of the impairment charge was $204.4 million, or $0.64 per share, after giving effect to the estimated fair value of the related land, reimbursement agreements, and the impact of expected income tax benefits associated with the impairment charge. As a result of the decision to terminate the NPT project and permanently abandon any further development, Eversource does not expect any future cash expenditures associated with this project.

E.     Cash

Cash includes cash on hand.  At the end of each reporting period, any overdraft amounts are reclassified from Cash to Accounts Payable on the balance sheets.

F.     Provision for Uncollectible Accounts

Eversource, including CL&P, NSTAR Electric and PSNH, presents its receivables at estimated net realizable value by maintaining a provision for uncollectible accounts.  This provision is determined based upon a variety of judgments and factors, including the application of an estimated uncollectible percentage to each receivable aging category.  The estimate is based upon historical collection and write-off experience and management's assessment of collectability from customers.  Management continuously assesses the collectability of receivables and adjusts collectability estimates based on actual experience.  Receivable balances are written off against the provision for uncollectible accounts when the customer accounts are terminated and these balances are deemed to be uncollectible.

The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively.  The DPU allows NSTAR Electric and NSTAR Gas to recover in rates, amounts associated with certain uncollectible hardship accounts receivable.  These uncollectible hardship customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets.  

The total provision for uncollectible accounts is included in Receivables, Net on the balance sheets. The provision for uncollectible hardship accounts is included in the total uncollectible provision balance. The provision balances were as follows:

	Total Provision for Uncollectible Accounts				Provision for Uncollectible Hardship Accounts
	As of December 31,				As of December 31,
(Millions of Dollars)	2019		2018		2019		2018
Eversource	$	224.8	$	212.7	$	143.3	$	131.5
CL&P	97.3		88.0		80.1		71.9
NSTAR Electric	75.4		74.5		43.9		42.5
PSNH	10.5		11.1		—		—

Uncollectible expense associated with customers' accounts receivable included in Operations and Maintenance expense on the statements of income was as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource	$	63.4	$	61.3	$	44.5
CL&P	15.9		15.8		5.3
NSTAR Electric	25.1		22.3		21.3
PSNH	6.7		6.4		6.7

G.    Transfer of Energy Efficiency Loans

In 2018, CL&P transferred $41.3 million of its energy efficiency customer loan portfolio to two outside lenders in order to make additional loans to customers.  CL&P remains the servicer of the loans and will transmit customer payments to the lenders.  Under a three-year agreement with the lenders, additional energy efficiency loans will also be transferred with a maximum amount outstanding under this program of $55 million.  The transaction did not qualify as a sale for accounting purposes, and the amounts of the loans are included in Accounts Receivable, Net and Other Long-Term Assets, and are offset by Other Current Liabilities and Other Long-Term Liabilities on CL&P’s balance sheet. The current and long-term portions totaled $16.5 million and $18.2 million, respectively, as of December 31, 2019, and $18.5 million and $22.8 million, respectively, as of December 31, 2018.

H.     Fuel, Materials, Supplies and REC Inventory

Fuel, Materials, Supplies and REC Inventory include natural gas inventory, materials and supplies purchased primarily for construction or operation and maintenance purposes, and RECs.  Inventory is valued at the lower of cost or net realizable value. RECs are purchased from suppliers of renewable sources of generation and are used to meet state mandated Renewable Portfolio Standards requirements.  The carrying amounts of fuel, materials and supplies, and RECs, which are included in Current Assets on the balance sheets, were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Fuel	$	26.7	$	—	$	—	$	—	$	33.1	$	—	$	—	$	—
Materials and Supplies	132.9		50.7		54.7		18.5		126.1		44.5		48.6		24.3
RECs	75.9		—		69.4		6.5		78.8		—		65.6		13.2
Total	$	235.5	$	50.7	$	124.1	$	25.0	$	238.0	$	44.5	$	114.2	$	37.5

    Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" (normal) and to the marketable securities held in trusts.  Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill, long-lived assets and AROs. We also applied this guidance in the valuation of our basis differences in our equity method offshore wind investments (see Note 6, "Investments in Unconsolidated Affiliates," for further information). The fair value measurement guidance was also applied in estimating the fair value of preferred stock, long-term debt and RRBs.

Fair Value Hierarchy:  In measuring fair value, Eversource uses observable market data when available in order to minimize the use of unobservable inputs.  Inputs used in fair value measurements are categorized into three fair value hierarchy levels for disclosure purposes.  The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement.  Eversource evaluates the classification of assets and liabilities measured at fair value on a quarterly basis, and Eversource's policy is to recognize transfers between levels of the fair value hierarchy as of the end of the reporting period.  The three levels of the fair value hierarchy are described below:

Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  

Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable.

Level 3 - Quoted market prices are not available.  Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable.  Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products.  

Uncategorized - Investments that are measured at net asset value are not categorized within the fair value hierarchy.

Determination of Fair Value:  The valuation techniques and inputs used in Eversource's fair value measurements are described in Note 4, "Derivative Instruments," Note 5, "Marketable Securities," Note 6, "Investments in Unconsolidated Affiliates," Note 7, "Asset Retirement Obligations," Note 11A, "Employee Benefits – Pension Benefits and Postretirement Benefits Other Than Pension," Note 16, "Fair Value of Financial Instruments" and Note 25B, "Acquisition of Aquarion and Goodwill - Goodwill" to the financial statements.

J.     Derivative Accounting

Many of the electric and natural gas companies' contracts for the purchase and sale of energy or energy-related products are derivatives.  The accounting treatment for energy contracts entered into varies and depends on the intended use of the particular contract and on whether or not the contract is a derivative.  

The application of derivative accounting is complex and requires management judgment in the following respects: identification of derivatives and embedded derivatives, election and designation of a contract as normal, and determination of the fair value of derivative contracts.  All of these judgments can have a significant impact on the financial statements.  The judgment applied in the election of a contract as normal (and resulting accrual accounting) includes the conclusion that it is probable at the inception of the contract and throughout its term that it will result in physical delivery of the underlying product and that the quantities will be used or sold by the business in the normal course of business.  If facts and circumstances change and management can no longer support this conclusion, then a contract cannot be considered normal, accrual accounting is terminated, and fair value accounting is applied prospectively.  

The fair value of derivative contracts is based upon the contract terms and conditions and the underlying market price or fair value per unit.  When quantities are not specified in the contract, the Company determines whether the contract has a determinable quantity by using amounts referenced in default provisions and other relevant sections of the contract.  The fair value of derivative assets and liabilities with the same counterparty are offset and recorded as a net derivative asset or liability on the balance sheets.  

Regulatory assets or regulatory liabilities are recorded to offset the fair values of derivative contracts related to energy and energy-related products, as contract settlements are recovered from, or refunded to, customers in future rates. All changes in the fair value of derivative contracts are recorded as regulatory assets or liabilities and do not impact net income.

For further information regarding derivative contracts, see Note 4, "Derivative Instruments," to the financial statements.

K.     Operating Expenses

Costs related to fuel and natural gas included in Purchased Power, Fuel and Transmission on the statements of income were as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource - Natural Gas and Fuel	$	462.1	$	442.6	$	432.5
PSNH - Fuel	—		7.9		43.4

PSNH completed the sale of its generation assets in 2018. See Note 14, "Generation Asset Sale," for further information.

    Allowance for Funds Used During Construction

AFUDC represents the cost of borrowed and equity funds used to finance construction and is included in the cost of the electric, natural gas and water companies' utility plant on the balance sheet.  The portion of AFUDC attributable to borrowed funds is recorded as a reduction of Interest Expense, and the AFUDC related to equity funds is recorded as Other Income, Net on the statements of income.  AFUDC costs are recovered from customers over the service life of the related plant in the form of increased revenue collected as a result of higher depreciation expense.

The average AFUDC rate is based on a FERC-prescribed formula using the cost of a company's short-term financings and capitalization (preferred stock, long-term debt and common equity), as appropriate.  The average rate is applied to average eligible CWIP amounts to calculate AFUDC.

AFUDC costs and the weighted-average AFUDC rates were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars, except percentages)	2019			2018			2017
Borrowed Funds	$	25.6		$	19.7		$	12.5
Equity Funds	45.0			44.0			34.4
Total AFUDC	$	70.6		$	63.7		$	46.9
Average AFUDC Rate	5.4		%	4.9		%	5.1		%

	For the Years Ended December 31,
	2019									2018									2017
(Millions of Dollars, except percentages)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Borrowed Funds	$	7.1		$	10.4		$	2.8		$	6.3		$	7.8		$	1.3		$	5.1		$	4.8		$	0.7
Equity Funds	13.2			19.8			3.4			12.2			15.6			—			12.1			10.2			—
Total AFUDC	$	20.3		$	30.2		$	6.2		$	18.5		$	23.4		$	1.3		$	17.2		$	15.0		$	0.7
Average AFUDC Rate	6.3		%	5.7		%	4.6		%	5.8		%	5.0		%	0.7		%	6.2		%	5.0		%	0.7		%

M.     Other Income, Net

The components of Other Income, Net on the statements of income were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018			2017
Pension, SERP and PBOP Non-Service Income Components	$	31.3	$	60.8		$	29.9
AFUDC Equity	45.0		44.0			34.4
Equity in Earnings of Unconsolidated Affiliates (1)	42.2		3.8			27.4
Investment Income/(Loss)	0.8		(4.0		)	7.5
Interest Income (2)	12.8		18.1			8.3
Gains on Sales of Property	0.3		5.1			—
Other	0.4		0.6			0.4
Total Other Income, Net	$	132.8	$	128.4		$	107.9

	For the Years Ended December 31,
	2019								2018									2017
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH		CL&P			NSTAR Electric			PSNH			CL&P		NSTAR Electric		PSNH
Pension, SERP and PBOP Non-Service   Income Components	$	0.5		$	23.5		$	4.9	$	9.5		$	36.0		$	9.9		$	1.8	$	19.2	$	5.9
AFUDC Equity	13.2			19.8			3.4		12.2			15.6			—			12.1		10.2		—
Equity in Earnings of Unconsolidated Affiliates	0.1			0.7			—		0.1			0.7			—			—		0.3		—
Investment Income/(Loss)	2.3			(0.4		)	0.3		(3.0		)	(0.5		)	(0.8		)	4.5		2.6		1.6
Interest Income (2)	1.5			0.7			10.5		3.7			0.8			14.1			4.6		1.8		2.2
Gains on Sales of Property	—			0.1			—		—			0.5			4.4			—		—		—
Other	(0.1		)	0.2			0.1		0.2			—			0.1			—		—		0.1
Total Other Income, Net	$	17.5		$	44.6		$	19.2	$	22.7		$	53.1		$	27.7		$	23.0	$	34.1	$	9.8

⁽¹⁾  Equity in earnings of unconsolidated affiliates includes an other-than-temporary impairment of $32.9 million of the Access Northeast project investment for the year ended December 31, 2018. See Note 6, "Investments in Unconsolidated Affiliates," for further information. Equity in earnings includes $20.4 million, $17.6 million and $9.7 million of pre-tax unrealized gains for the years ended December 31, 2019, 2018 and 2017, respectively, associated with an equity method investment in a renewable energy fund.

⁽²⁾ For the years ended December 31, 2019 and 2018, PSNH recognized $6.3 million and $8.7 million, respectively, of interest income for the equity return component of carrying charges on storm costs approved in 2019 and 2018. See Note 2, "Regulatory Accounting," for further information.

N.     Other Taxes

Eversource's companies that serve customers in Connecticut collect gross receipts taxes levied by the state of Connecticut from their customers. These gross receipts taxes are recorded separately with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the statements of income as follows:

	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Eversource	$	163.1	$	161.9	$	157.4
CL&P	141.1		141.4		137.5

As agents for state and local governments, Eversource's companies that serve customers in Connecticut and Massachusetts collect certain sales taxes that are recorded on a net basis with no impact on the statements of income.  

Separate from above were amounts recorded as Taxes Other Than Income Taxes related to the remittance to the State of Connecticut of energy efficiency funds collected from customers in Operating Revenues. These amounts were $21.4 million and $46.8 million in 2019 and 2018, respectively. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. These amounts were recorded separately, with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the Eversource and CL&P statements of income.

O.     Supplemental Cash Flow Information

Eversource (Millions of Dollars)	As of and For the Years Ended December 31,
	2019		2018		2017
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	$	532.4	$	503.2	$	419.1
Income Taxes	56.0		158.8		30.8
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of) (1)	379.4		389.3		379.5

	As of and For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	$	144.6	$	121.9	$	56.9	$	149.7	$	122.1	$	40.5	$	144.6	$	124.6	$	45.9
Income Taxes	80.6		77.9		3.4		66.1		120.0		27.3		68.8		95.5		26.1
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of) (1)	111.3		116.4		49.9		106.1		116.5		35.1		132.5		116.5		44.4

⁽¹⁾ See Note 1B, "Summary of Significant Accounting Policies - Basis of Presentation," for information regarding the correction of non-cash capital additions at Eversource and PSNH reported as of December 31, 2018.

Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan. The issuance of treasury shares represents a non-cash transaction, as the treasury shares were used to fulfill Eversource's obligations that require the issuance of common shares.

The following table reconciles cash as reported on the balance sheets to the cash and restricted cash balance as reported on the statements of cash flows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Cash as reported on the Balance Sheets	$	15.4	$	—	$	0.1	$	0.4	$	108.1	$	87.7	$	1.6	$	1.4
Restricted cash included in:
Special Deposits	52.5		4.6		6.2		32.5		72.1		3.5		13.0		47.5
Marketable Securities	46.0		0.4		—		0.6		25.9		0.4		0.1		0.6
Other Long-Term Assets	3.2		—		—		3.2		3.2		—		—		3.2
Cash and Restricted Cash reported on the     Statements of Cash Flows	$	117.1	$	5.0	$	6.3	$	36.7	$	209.3	$	91.6	$	14.7	$	52.7

Special Deposits represent cash collections related to the PSNH RRB customer charges that are held in trust and required ISO-NE cash deposits, and are included in Current Assets on the balance sheets. Restricted cash included in Marketable Securities represents money market funds held in trusts to fund certain non-qualified executive benefits and restricted trusts to fund CYAPC and YAEC's spent nuclear fuel storage obligations.

P.     Related Parties

Eversource Service, Eversource's service company, provides centralized accounting, administrative, engineering, financial, information technology, legal, operational, planning, purchasing, tax, and other services to Eversource's companies.  The Rocky River Realty Company, Renewable Properties, Inc. and Properties, Inc., three other Eversource subsidiaries, construct, acquire or lease some of the property and facilities used by Eversource's companies.

As of both December 31, 2019 and 2018, CL&P, NSTAR Electric and PSNH had long-term receivables from Eversource Service in the amounts of $25.0 million, $5.5 million and $3.8 million, respectively, which were included in Other Long-Term Assets on the balance sheets. These amounts related to the funding of investments held in trust by Eversource Service in connection with certain postretirement benefits for CL&P, NSTAR Electric and PSNH employees and have been eliminated in consolidation on the Eversource financial statements.  

Included in the CL&P, NSTAR Electric and PSNH balance sheets as of December 31, 2019 and 2018 were Accounts Receivable from Affiliated Companies and Accounts Payable to Affiliated Companies relating to transactions between CL&P, NSTAR Electric and PSNH and other subsidiaries that are wholly-owned by Eversource.  These amounts have been eliminated in consolidation on the Eversource financial statements.

Q.     Acquisition of Assets of Columbia Gas of Massachusetts

On February 26, 2020, Eversource and NiSource entered into an asset purchase agreement (the Agreement) pursuant to which Eversource would acquire the assets that comprise NiSource’s local gas distribution business in Massachusetts, which is doing business as Columbia Gas of Massachusetts (CMA). The purchase price of $1.1 billion includes a target working capital amount that would be adjusted to reflect actual working capital as of the closing date. The acquisition and resulting rate plan both require DPU and other approvals.

The liabilities to be assumed by Eversource under the Agreement specifically exclude any liabilities (past or future) arising out of or related to the fires and explosions that occurred on September 13, 2018 in Lawrence, Andover and North Andover, Massachusetts related to the delivery of natural gas by CMA, including certain subsequent events, all as described and in the DPU's Order on Scope dated December 23, 2019 (D.P.U. 19-141) (the Greater Lawrence Incident or GLI), and any further emergency events prior to the closing of the acquisition related to the restoration and reconstruction with respect to the GLI, including any losses arising out of or related to any litigation, demand, cause of action, claim, suit, investigation, proceeding, indemnification agreements or rights.

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INCOME TAXES - Narrative (Details) - State and Local Jurisdiction - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Operating Loss Carryforwards [Line Items]
Valuation allowance for tax credit and operating loss carryforward	$ 43.0	$ 19.5
Eversource
Operating Loss Carryforwards [Line Items]
Change in valuation allowance	18.5	5.2
CL&P
Operating Loss Carryforwards [Line Items]
Change in valuation allowance	$ 14.2	$ 4.4

XML

INCOME TAXES - Components of Income Tax Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Current Income Taxes:
Federal	$ 56,900	$ 106,500	$ 58,900
State	10,500	10,600	31,600
Total Current	67,400	117,100	90,500
Deferred Income Taxes, Net:
Federal	138,400	122,600	433,000
State	71,400	52,200	58,600
Total Deferred	209,812	174,812	491,630
Investment Tax Credits, Net	(3,700)	(2,900)	(3,200)
Income Tax Expense	273,499	288,972	578,892
CL&P
Current Income Taxes:
Federal	68,400	54,200	50,900
State	15,400	20,900	17,400
Total Current	83,800	75,100	68,300
Deferred Income Taxes, Net:
Federal	35,200	48,500	123,900
State	18,800	6,400	(4,600)
Total Deferred	54,005	54,859	119,295
Investment Tax Credits, Net	(800)	(900)	(1,000)
Income Tax Expense	136,971	129,056	186,646
NSTAR Electric
Current Income Taxes:
Federal	82,600	79,300	107,800
State	18,200	30,000	25,600
Total Current	100,800	109,300	133,400
Deferred Income Taxes, Net:
Federal	100	27,900	88,100
State	27,000	13,500	22,400
Total Deferred	27,107	41,438	110,499
Investment Tax Credits, Net	(2,600)	(1,800)	(1,800)
Income Tax Expense	125,313	148,906	242,085
PSNH
Current Income Taxes:
Federal	22,900	12,200	18,600
State	2,200	(500)	6,200
Total Current	25,100	11,700	24,800
Deferred Income Taxes, Net:
Federal	5,800	15,400	52,700
State	10,100	20,500	11,200
Total Deferred	15,917	35,924	63,883
Investment Tax Credits, Net	0	0	0
Income Tax Expense	$ 40,975	$ 47,576	$ 88,675

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EARNINGS PER SHARE

12 Months Ended

Dec. 31, 2019

Earnings Per Share [Abstract]

EARNINGS PER SHARE

EARNINGS PER SHARE

Basic EPS is computed based upon the weighted average number of common shares outstanding during each period.  Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards and the equity forward sale agreement, as if they were converted into outstanding common shares.  The dilutive effect of unvested RSU and performance share awards, as well as the equity forward sale agreement, is calculated using the treasury stock method.  RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied.  

As described in Note 19, "Common Shares," earnings per share dilution, if any, related to the forward sale agreement will be determined under the treasury stock method until settlement of the forward sale agreement. Under this method, the number of Eversource common shares used in calculating diluted EPS is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreement less the number of shares that would be purchased by Eversource in the market (based on the average market price during the same reporting period) using the proceeds receivable upon settlement (based on the adjusted forward sale price at the end of that reporting period). Share dilution occurs when the average market price of Eversource's common shares is higher than the adjusted forward sale price.

The following table sets forth the components of basic and diluted EPS:

Eversource (Millions of Dollars, except share information)	For the Years Ended December 31,
	2019		2018		2017
Net Income Attributable to Common Shareholders	$	909.1	$	1,033.0	$	988.0
Weighted Average Common Shares Outstanding:
Basic	321,416,086		317,370,369		317,411,097
Dilutive Effect of:
Share-Based Compensation Awards and Other	762,215		623,565		620,483
Equity Forward Sale Agreement	763,335		—		—
Total Dilutive Effect	1,525,550		623,565		620,483
Diluted	322,941,636		317,993,934		318,031,580
Basic EPS	$	2.83	$	3.25	$	3.11
Diluted EPS	$	2.81	$	3.25	$	3.11

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FAIR VALUE OF FINANCIAL INSTRUMENTS - Fair Value Hierarchy (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	$ 155,570	$ 155,570
Rate Reduction Bonds	540,122	583,331
Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	155,600	155,600
Long-Term Debt	14,098,200	13,086,100
Rate Reduction Bonds	583,300	635,700
Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	162,000	156,800
Long-Term Debt	15,170,200	13,154,900
Rate Reduction Bonds	625,900	645,800
CL&P
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	116,200	116,200
CL&P | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	116,200	116,200
Long-Term Debt	3,518,100	3,254,000
CL&P | Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	117,800	113,800
Long-Term Debt	4,058,000	3,429,200
NSTAR Electric
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	43,000	43,000
NSTAR Electric | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	43,000	43,000
Long-Term Debt	3,342,100	2,944,800
NSTAR Electric | Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	44,200	43,000
Long-Term Debt	3,659,900	3,024,100
PSNH
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rate Reduction Bonds	540,122	583,331
PSNH | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	0	0
Long-Term Debt	951,600	805,200
Rate Reduction Bonds	583,300	635,700
PSNH | Fair Value
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	0	0
Long-Term Debt	1,005,700	819,500
Rate Reduction Bonds	$ 625,900	$ 645,800

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GENERATION ASSET SALE

12 Months Ended

Dec. 31, 2019

Regulated Operations [Abstract]

GENERATION ASSET SALE

GENERATION ASSET SALE

On January 10, 2018, PSNH completed the sale of its thermal generation assets. The original purchase price of $175 million was adjusted to reflect working capital adjustments, closing date adjustments and proration of taxes and fees prior to closing. As a result of these adjustments, net proceeds from the sale of the thermal assets totaled $116.8 million. On August 26, 2018, PSNH completed the sale of its hydroelectric generation assets. The original purchase price of $83 million was adjusted to reflect contractual adjustments totaling $5.8 million, resulting in net proceeds of $77.2 million. The difference between the carrying value of the hydroelectric generation assets and the sale proceeds resulted in a gain of $17.3 million. An estimated gain from the sale of these assets was included as an offset to the total remaining costs associated with the sale of generation assets that were securitized on May 8, 2018.

On May 8, 2018, PSNH Funding issued $635.7 million of securitized RRBs to finance PSNH's unrecovered remaining costs resulting from the divestiture of its generation assets, which included the deferred costs resulting from the sale of the thermal generation assets. These RRBs are secured by a non-bypassable charge recoverable from PSNH customers. PSNH recorded regulatory assets and other deferred costs in connection with the generation asset divestiture and the securitization of remaining costs, which are probable of recovery through collection of the non-bypassable charge. As of December 31, 2019 and 2018, unamortized securitized stranded costs totaled $565.3 million and $608.4 million, respectively, and are included in Regulatory Assets on the Eversource and PSNH balance sheets. For further information on the securitized RRB issuance, see Note 10, "Rate Reduction Bonds and Variable Interest Entities."

On November 27, 2019, PSNH filed a motion for the commencement of audit of divestiture-related costs. PSNH’s actual balance of costs eligible for recovery as divestiture-related costs is $654.0 million, which is above the $635.7 million amount securitized in May 2018. PSNH proposed to recover this balance through the SCRC tracker mechanism and believes the amount deferred is probable of recovery. These deferred costs are recorded in Other Long-Term Assets on the balance sheet.

For the year ended December 31, 2018, pre-tax income associated with the hydroelectric assets prior to the sale on August 26, 2018 was $9.9 million. For the year ended December 31, 2017, pre-tax income associated with PSNH's generation assets was $60.0 million. As of December 31, 2018, all generation assets had been sold.

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LEASES - Narrative (Details)	12 Months Ended
	Dec. 31, 2019
Minimum
Lessee, Lease, Description [Line Items]
Renewal period	1 year
Maximum
Lessee, Lease, Description [Line Items]
Renewal period	20 years
CL&P | Minimum
Lessee, Lease, Description [Line Items]
Renewal period	1 year
CL&P | Maximum
Lessee, Lease, Description [Line Items]
Renewal period	20 years
NSTAR Electric | Minimum
Lessee, Lease, Description [Line Items]
Renewal period	1 year
NSTAR Electric | Maximum
Lessee, Lease, Description [Line Items]
Renewal period	20 years
PSNH | Minimum
Lessee, Lease, Description [Line Items]
Renewal period	1 year
PSNH | Maximum
Lessee, Lease, Description [Line Items]
Renewal period	20 years

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LEASES - Other Information Related to Leases (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($)
Weighted-Average Remaining Lease Term (Years):
Operating Leases	12 years
Finance Leases	12 years
Weighted-Average Discount Rate (Percentage):
Operating Leases	3.90%
Finance Leases	4.00%
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$ 11.4
Operating Cash Flows from Finance Leases	1.2
Financing Cash Flows from Finance Leases	2.6
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	2.9
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	$ 2.0
CL&P
Weighted-Average Remaining Lease Term (Years):
Operating Leases	2 years
Finance Leases	2 years
Weighted-Average Discount Rate (Percentage):
Operating Leases	2.50%
Finance Leases	10.50%
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$ 0.4
Operating Cash Flows from Finance Leases	0.6
Financing Cash Flows from Finance Leases	1.4
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	1.0
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	$ 0.0
NSTAR Electric
Weighted-Average Remaining Lease Term (Years):
Operating Leases	20 years
Finance Leases	22 years
Weighted-Average Discount Rate (Percentage):
Operating Leases	4.10%
Finance Leases	2.90%
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$ 1.6
Operating Cash Flows from Finance Leases	0.6
Financing Cash Flows from Finance Leases	0.0
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	0.1
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	$ 0.0
PSNH
Weighted-Average Remaining Lease Term (Years):
Operating Leases	9 years
Finance Leases	9 years
Weighted-Average Discount Rate (Percentage):
Operating Leases	3.70%
Finance Leases	3.50%
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$ 0.1
Operating Cash Flows from Finance Leases	0.0
Financing Cash Flows from Finance Leases	0.1
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	0.2
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	$ 0.0

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DIVIDEND RESTRICTIONS

12 Months Ended

Dec. 31, 2019

Equity [Abstract]

DIVIDEND RESTRICTIONS

DIVIDEND RESTRICTIONS

Eversource parent's ability to pay dividends may be affected by certain state statutes, the ability of its subsidiaries to pay common dividends and the leverage restriction tied to its consolidated total debt to total capitalization ratio requirement in its revolving credit agreement.  Pursuant to the joint revolving credit agreement of Eversource, CL&P, PSNH, NSTAR Gas, Yankee Gas and Aquarion Water Company of Connecticut, and to the NSTAR Electric revolving credit agreement, each company is required to maintain consolidated total indebtedness to total capitalization ratio of no greater than 65 percent at the end of each fiscal quarter. As of December 31, 2019, all companies were in compliance with such covenant and in compliance with all such provisions of the revolving credit agreements that may restrict the payment of dividends as of December 31, 2019.

The Retained Earnings balances subject to dividend restrictions were $4.2 billion for Eversource, $1.8 billion for CL&P, $2.3 billion for NSTAR Electric and $490.3 million for PSNH as of December 31, 2019.

CL&P, NSTAR Electric and PSNH are subject to Section 305 of the Federal Power Act that makes it unlawful for a public utility to make or pay a dividend from any funds "properly included in its capital account." Management believes that this Federal Power Act restriction, as applied to CL&P, NSTAR Electric and PSNH, would not be construed or applied by the FERC to prohibit the payment of dividends from retained earnings for lawful and legitimate business purposes. In addition, certain state statutes may impose additional limitations on such companies and on NSTAR Gas, Yankee Gas, Aquarion Water Company of Connecticut, Aquarion Water Company of Massachusetts and Aquarion Water Company of New Hampshire. Such state law restrictions do not restrict the payment of dividends from retained earnings or net income.

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ACQUISITION OF AQUARION AND GOODWILL - Schedule of Pro Forma Information (Details) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017 USD ($) $ / shares
Business Acquisition [Line Items]
Operating Revenues	$ 15.9
Aquarion Water Company
Business Acquisition [Line Items]
Operating Revenues	7,947.7
Net Income Attributable to Common Shareholders	$ 1,019.1
Basic EPS (in dollars per share) | $ / shares	$ 3.21
Diluted EPS (in dollars per share) | $ / shares	$ 3.20

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SHORT-TERM DEBT (Tables)

12 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]

Schedule of Borrowings Outstanding

The amount of borrowings outstanding and available under the commercial paper programs were as follows:

	Borrowings Outstanding  as of December 31,				Available Borrowing Capacity as of December 31,				Weighted-Average Interest Rate as of December 31,
(Millions of Dollars)	2019		2018		2019		2018		2019		2018
Eversource Parent Commercial Paper Program	$	1,224.9	$	631.5	$	225.1	$	818.5	1.98	%	2.77	%
NSTAR Electric Commercial Paper Program	10.5		278.5		639.5		371.5		1.63	%	2.50	%

Details of long-term debt outstanding are as follows:

CL&P (Millions of Dollars)	As of December 31,
	2019			2018
First Mortgage Bonds:
7.875% 1994 Series D due 2024	$	139.8		$	139.8
5.750% 2004 Series B due 2034	130.0			130.0
5.625% 2005 Series B due 2035	100.0			100.0
6.350% 2006 Series A due 2036	250.0			250.0
5.750% 2007 Series B due 2037	150.0			150.0
6.375% 2007 Series D due 2037	100.0			100.0
5.500% 2009 Series A due 2019	—			250.0
2.500% 2013 Series A due 2023	400.0			400.0
4.300% 2014 Series A due 2044	475.0			475.0
4.150% 2015 Series A due 2045	350.0			350.0
3.200% 2017 Series A due 2027	500.0			300.0
4.000% 2018 Series A due 2048	800.0			500.0
Total First Mortgage Bonds	3,394.8			3,144.8
Pollution Control Revenue Bonds:
4.375% Fixed Rate Tax Exempt due 2028	120.5			120.5
Less Amounts due Within One Year	—			(250.0		)
Unamortized Premiums and Discounts, Net	27.8			10.2
Unamortized Debt Issuance Costs	(25.0		)	(21.5		)
CL&P Long-Term Debt	$	3,518.1		$	3,004.0

NSTAR Electric (Millions of Dollars)	As of December 31,
	2019			2018
Debentures:
5.750% due 2036	$	200.0		$	200.0
5.500% due 2040	300.0			300.0
2.375% due 2022	400.0			400.0
4.400% due 2044	300.0			300.0
3.250% due 2025	250.0			250.0
2.700% due 2026	250.0			250.0
3.200% due 2027	700.0			700.0
3.250% due 2029	400.0			—
Total Debentures	2,800.0			2,400.0
Notes:
5.900% Senior Notes Series B due 2034	50.0			50.0
6.700% Senior Notes Series D due 2037	40.0			40.0
5.100% Senior Notes Series E due 2020	95.0			95.0
3.500% Senior Notes Series F due 2021	250.0			250.0
3.880% Senior Notes Series G due 2023	80.0			80.0
2.750% Senior Notes Series H due 2026	50.0			50.0
Total Notes	565.0			565.0
Less Amounts due Within One Year	(95.0		)	—
Unamortized Premiums and Discounts, Net	(4.1		)	(2.5		)
Unamortized Debt Issuance Costs	(18.8		)	(17.7		)
NSTAR Electric Long-Term Debt	$	3,247.1		$	2,944.8

PSNH (Millions of Dollars)	As of December 31,
	2019			2018
First Mortgage Bonds:
5.600% Series M due 2035	$	50.0		$	50.0
4.500% Series P due 2019	—			150.0
4.050% Series Q due 2021	122.0			122.0
3.200% Series R due 2021	160.0			160.0
3.500% Series S due 2023	325.0			325.0
3.600% Series T due 2049	300.0			—
Total First Mortgage Bonds	957.0			807.0
Less Amounts due Within One Year	—			(150.0		)
Unamortized Premiums and Discounts, Net	(0.7		)	—
Unamortized Debt Issuance Costs	(4.7		)	(1.8		)
PSNH Long-Term Debt	$	951.6		$	655.2

OTHER (Millions of Dollars)	As of December 31,
	2019			2018
Yankee Gas - First Mortgage Bonds: 2.230% - 8.480% due 2020 - 2049	$	620.0		$	470.0
NSTAR Gas - First Mortgage Bonds: 3.740% - 9.950% due 2020 - 2049	460.0			385.0
Aquarion - Senior Note 4.000% due 2024	360.0			360.0
Aquarion - Unsecured Notes 0% - 6.430% due 2021 - 2049	335.3			289.5
Aquarion - Secured Debt 4.100% - 9.640% due 2021 - 2035	68.8			70.7
Eversource Parent - Debentures 4.500% due 2019	—			350.0
Eversource Parent - Senior Notes 2.500% - 4.250% due 2021 - 2029	4,000.0			4,000.0
Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)	11.6			39.5
Fair Value Adjustment (1)	109.1			144.7
Less Fair Value Adjustment - Current Portion (1)	(31.3		)	(36.2		)
Less Amounts due in One Year	(201.1		)	(401.1		)
Commercial Paper Classified as Long-Term Debt (See Note 8, Short-Term Debt)	346.3			—
Unamortized Premiums and Discounts, Net	(4.1		)	(4.2		)
Unamortized Debt Issuance Costs	(20.6		)	(23.2		)
Total Other Long-Term Debt	$	6,054.0		$	5,644.7
Total Eversource Long-Term Debt	$	13,770.8		$	12,248.7

⁽¹⁾ The fair value adjustment amount is the purchase price adjustments, net of amortization, required to record long-term debt at fair value on the dates of the 2012 merger with NSTAR and the 2017 acquisition of Aquarion.

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DERIVATIVE INSTRUMENTS (Tables)

12 Months Ended

Dec. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

The following table presents the gross fair values of contracts, categorized by risk type, and the net amounts recorded as current or long-term derivative assets or liabilities:

		As of December 31,
		2019									2018
(Millions of Dollars)	Fair Value Hierarchy	Commodity Supply and Price Risk Management			Netting (1)			Net Amount Recorded as a Derivative			Commodity Supply and Price Risk Management			Netting (1)			Net Amount Recorded as a Derivative
Current Derivative Assets:
CL&P	Level 3	$	12.2		$	(0.4	)	$	11.8		$	9.6		$	(3.4	)	$	6.2
Other	Level 2	—			—			—			1.5			(0.9		)	0.6
Long-Term Derivative Assets:
CL&P	Level 3	67.5			(2.1		)	65.4			74.2			(2.3		)	71.9
Current Derivative Liabilities:
CL&P	Level 3	(67.8		)	—			(67.8		)	(55.1		)	—			(55.1		)
Other	Level 2	(5.2		)	—			(5.2		)	—			—			—
Long-Term Derivative Liabilities:
CL&P	Level 3	(338.6		)	—			(338.6		)	(379.5		)	—			(379.5		)
Other	Level 2	(0.1		)	—			(0.1		)	—			—			—

⁽¹⁾

Amounts represent derivative assets and liabilities that Eversource elected to record net on the balance sheets.  These amounts are subject to master netting agreements or similar agreements for which the right of offset exists.

Fair Value Inputs, Liabilities, Quantitative Information

The following is a summary of Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts:

	As of December 31,
	2019						2018
CL&P	Range					Period Covered	Range					Period Covered
Capacity Prices	$	3.01	—	7.34	per kW-Month	2023 - 2026	$	4.30	—	7.44	per kW-Month	2022 - 2026
Forward Reserve	0.80		—	1.90	per kW-Month	2020 - 2024	0.75		—	1.78	per kW-Month	2019 - 2024

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation

The following table presents changes in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis.  The derivative assets and liabilities are presented on a net basis.

CL&P (Millions of Dollars)	For the Years Ended December 31,
	2019			2018
Derivatives, Net:
Fair Value as of Beginning of Period	$	(356.5	)	$	(362.3	)
Net Realized/Unrealized Losses Included in Regulatory Assets	(15.0		)	(32.0		)
Settlements	42.3			37.8
Fair Value as of End of Period	$	(329.2	)	$	(356.5	)

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REVENUES (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									$ 8,450,000	$ 8,472,700
Alternative Revenue Programs									53,200	(46,100)
Other Revenues									23,300	21,600
Operating Revenues	$ 2,050,400	$ 2,175,800	$ 1,884,500	$ 2,415,800	$ 2,034,900	$ 2,271,400	$ 1,853,900	$ 2,288,000	8,526,470	8,448,201	$ 7,751,952
Lease revenue									4,400
Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									4,411,100	4,439,800
Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									2,992,000	3,028,300
Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									421,600	442,300
Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									7,824,700	7,910,400
Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									269,400	264,000
Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									275,200	241,100
Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									76,000	81,500
Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									4,700	(24,300)
CL&P
Disaggregation of Revenue [Line Items]
Operating Revenues	788,700	853,900	740,800	849,200	751,300	865,000	694,900	785,000	3,232,551	3,096,174	2,887,359
Lease revenue									1,000
NSTAR Electric
Disaggregation of Revenue [Line Items]
Operating Revenues	686,400	878,700	681,900	797,600	712,600	939,500	690,700	770,100	3,044,642	3,112,926	2,980,629
Lease revenue									2,700
PSNH
Disaggregation of Revenue [Line Items]
Operating Revenues	$ 268,200	$ 280,400	$ 240,900	$ 276,400	$ 254,900	$ 290,200	$ 235,100	$ 267,400	1,065,936	1,047,619	981,624
Operating Segments | Electric Distribution
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									6,912,100	6,986,300
Alternative Revenue Programs									45,900	(47,000)
Other Revenues									18,500	17,900
Operating Revenues									6,976,500	6,957,200	5,542,900
Operating Segments | Electric Distribution | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									3,723,700	3,766,600
Operating Segments | Electric Distribution | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									2,584,800	2,634,700
Operating Segments | Electric Distribution | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									331,800	351,900
Operating Segments | Electric Distribution | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									6,640,300	6,753,200
Operating Segments | Electric Distribution | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Electric Distribution | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									215,700	179,500
Operating Segments | Electric Distribution | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									54,800	65,900
Operating Segments | Electric Distribution | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,300	(12,300)
Operating Segments | Natural Gas Distribution
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,064,000	1,020,300
Alternative Revenue Programs									(4,900)	(1,200)
Other Revenues									3,100	3,100
Operating Revenues									1,062,200	1,022,200	947,300
Operating Segments | Natural Gas Distribution | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									555,100	542,500
Operating Segments | Natural Gas Distribution | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									347,600	334,800
Operating Segments | Natural Gas Distribution | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									96,900	96,000
Operating Segments | Natural Gas Distribution | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									999,600	973,300
Operating Segments | Natural Gas Distribution | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Natural Gas Distribution | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									55,400	57,500
Operating Segments | Natural Gas Distribution | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									2,800	(2,200)
Operating Segments | Natural Gas Distribution | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									6,200	(8,300)
Operating Segments | Electric Transmission
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,306,500	1,321,500
Alternative Revenue Programs									81,800	(35,200)
Other Revenues									700	0
Operating Revenues									1,389,000	1,286,300	1,301,700
Operating Segments | Electric Transmission | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Electric Transmission | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Electric Transmission | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Electric Transmission | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Electric Transmission | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,293,300	1,308,900
Operating Segments | Electric Transmission | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Electric Transmission | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									13,200	12,600
Operating Segments | Electric Transmission | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Water Distribution
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									209,000	206,000
Alternative Revenue Programs									4,600	5,400
Other Revenues									1,000	600
Operating Revenues									214,600	212,000
Operating Segments | Water Distribution | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									132,300	130,700
Operating Segments | Water Distribution | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									63,900	63,300
Operating Segments | Water Distribution | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									4,500	4,400
Operating Segments | Water Distribution | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									200,700	198,400
Operating Segments | Water Distribution | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | Water Distribution | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									4,100	4,100
Operating Segments | Water Distribution | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									7,000	7,200
Operating Segments | Water Distribution | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									(2,800)	(3,700)
Operating Segments | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									3,626,900	3,607,900
Alternative Revenue Programs									77,500	(65,900)
Other Revenues									10,300	8,500
Operating Segments | CL&P | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,837,100	1,828,200
Operating Segments | CL&P | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									922,900	928,100
Operating Segments | CL&P | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									138,300	147,700
Operating Segments | CL&P | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									2,898,300	2,904,000
Operating Segments | CL&P | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									587,100	620,600
Operating Segments | CL&P | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									105,100	48,300
Operating Segments | CL&P | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									36,400	35,000
Operating Segments | CL&P | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									3,396,400	3,491,100
Alternative Revenue Programs									41,600	900
Other Revenues									7,000	8,300
Operating Segments | NSTAR Electric | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,322,100	1,380,900
Operating Segments | NSTAR Electric | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,349,400	1,391,500
Operating Segments | NSTAR Electric | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									115,800	124,900
Operating Segments | NSTAR Electric | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									2,787,300	2,897,300
Operating Segments | NSTAR Electric | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									517,300	488,800
Operating Segments | NSTAR Electric | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									73,100	76,100
Operating Segments | NSTAR Electric | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									18,700	28,900
Operating Segments | NSTAR Electric | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Operating Segments | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,200,100	1,213,000
Alternative Revenue Programs									8,600	(17,300)
Other Revenues									1,900	1,100
Operating Segments | PSNH | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									564,500	557,500
Operating Segments | PSNH | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									314,600	316,900
Operating Segments | PSNH | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									77,700	79,300
Operating Segments | PSNH | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									956,800	953,700
Operating Segments | PSNH | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									188,900	199,500
Operating Segments | PSNH | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									37,500	56,600
Operating Segments | PSNH | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									15,600	15,500
Operating Segments | PSNH | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,300	(12,300)
Other
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									1,028,500	936,300
Alternative Revenue Programs									0	0
Other Revenues									0	0
Operating Revenues									1,028,500	936,300	931,000
Other | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Other | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Other | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Other | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Other | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									61,300	47,300
Other | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Other | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									967,200	889,000
Other | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Eliminations
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									(2,070,100)	(1,997,700)
Alternative Revenue Programs									(74,200)	31,900
Other Revenues									0	0
Operating Revenues									(2,144,300)	(1,965,800)	$ (986,800)
Eliminations | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Eliminations | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									(4,300)	(4,500)
Eliminations | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									(11,600)	(10,000)
Eliminations | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									(15,900)	(14,500)
Eliminations | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									(1,085,200)	(1,092,200)
Eliminations | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Eliminations | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									(969,000)	(891,000)
Eliminations | Reserve for Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers									0	0
Consolidations Eliminations | CL&P
Disaggregation of Revenue [Line Items]
Operating Revenues									(482,100)	(454,300)
Consolidations Eliminations | NSTAR Electric
Disaggregation of Revenue [Line Items]
Operating Revenues									(400,400)	(387,400)
Consolidations Eliminations | PSNH
Disaggregation of Revenue [Line Items]
Operating Revenues									$ (144,700)	$ (149,200)

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INCOME TAXES (Tables)

12 Months Ended

Dec. 31, 2019

Income Tax Disclosure [Abstract]

Components of Income Tax Expense

The components of income tax expense are as follows:

Eversource (Millions of Dollars)	For the Years Ended December 31,
	2019			2018			2017
Current Income Taxes:
Federal	$	56.9		$	106.5		$	58.9
State	10.5			10.6			31.6
Total Current	67.4			117.1			90.5
Deferred Income Taxes, Net:
Federal	138.4			122.6			433.0
State	71.4			52.2			58.6
Total Deferred	209.8			174.8			491.6
Investment Tax Credits, Net	(3.7		)	(2.9		)	(3.2		)
Income Tax Expense	$	273.5		$	289.0		$	578.9

	For the Years Ended December 31,
	2019								2018									2017
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH		CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Current Income Taxes:
Federal	$	68.4		$	82.6		$	22.9	$	54.2		$	79.3		$	12.2		$	50.9		$	107.8		$	18.6
State	15.4			18.2			2.2		20.9			30.0			(0.5		)	17.4			25.6			6.2
Total Current	83.8			100.8			25.1		75.1			109.3			11.7			68.3			133.4			24.8
Deferred Income Taxes, Net:
Federal	35.2			0.1			5.8		48.5			27.9			15.4			123.9			88.1			52.7
State	18.8			27.0			10.1		6.4			13.5			20.5			(4.6		)	22.4			11.2
Total Deferred	54.0			27.1			15.9		54.9			41.4			35.9			119.3			110.5			63.9
Investment Tax Credits, Net	(0.8		)	(2.6		)	—		(0.9		)	(1.8		)	—			(1.0		)	(1.8		)	—
Income Tax Expense	$	137.0		$	125.3		$	41.0	$	129.1		$	148.9		$	47.6		$	186.6		$	242.1		$	88.7

Summary of Reconciliation Between Income Tax Expense and Expected Tax

A reconciliation between income tax expense and the expected tax expense at the statutory rate is as follows:

Eversource (Millions of Dollars, except percentages)	For the Years Ended December 31,
	2019			2018			2017
Income Before Income Tax Expense	$	1,190.1		$	1,329.5		$	1,574.4
Statutory Federal Income Tax Expense at 21% in 2019 and 2018,   and 35% in 2017	249.9			279.2			551.0
Tax Effect of Differences:
Depreciation	1.9			(30.8		)	(10.8		)
Investment Tax Credit Amortization	(3.7		)	(2.9		)	(3.2		)
State Income Taxes, Net of Federal Impact	24.6			44.4			47.7
Dividends on ESOP	(5.1		)	(5.1		)	(8.4		)
Tax Asset Valuation Allowance/Reserve Adjustments	40.1			5.2			7.0
Excess Stock Benefit	(1.5		)	(1.5		)	(2.9		)
EDIT Amortization	(37.4		)	(5.0		)	—
Other, Net	4.7			5.5			(1.5		)
Income Tax Expense	$	273.5		$	289.0		$	578.9
Effective Tax Rate	23.0		%	21.7		%	36.8		%

	For the Years Ended December 31,
	2019									2018									2017
(Millions of Dollars, except percentages)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Income Before Income Tax Expense	$	547.8		$	557.3		$	175.0		$	506.8		$	532.0		$	163.5		$	563.4		$	616.8		$	224.7
Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017	115.0			117.0			36.8			106.4			111.7			34.3			197.2			215.9			78.6
Tax Effect of Differences:
Depreciation	(0.2		)	(3.0		)	(0.8		)	(1.2		)	(2.8		)	0.1			(5.2		)	(3.0		)	1.1
Investment Tax Credit Amortization	(0.8		)	(2.6		)	—			(0.9		)	(1.8		)	—			(1.0		)	(1.8		)	—
State Income Taxes,   Net of Federal Impact	2.5			35.7			9.8			14.5			33.2			15.8			4.5			31.2			11.3
Tax Asset Valuation   Allowance/Reserve Adjustments	24.5			—			—			7.1			1.2			—			(9.5		)	—			—
Excess Stock Benefit	(0.5		)	(0.5		)	(0.2		)	(0.1		)	(0.1		)	(0.1		)	(0.7		)	(0.7		)	(0.3		)
EDIT Amortization	(5.8		)	(22.9		)	(4.0		)	—			—			(4.4		)	—			—			—
Other, Net	2.3			1.6			(0.6		)	3.3			7.5			1.9			1.3			0.5			(2.0		)
Income Tax Expense	$	137.0		$	125.3		$	41.0		$	129.1		$	148.9		$	47.6		$	186.6		$	242.1		$	88.7
Effective Tax Rate	25.0		%	22.5		%	23.4		%	25.5		%	28.0		%	29.1		%	33.1		%	39.2		%	39.5		%

Schedule of Accumulated Deferred Income Tax Obligations

The tax effects of temporary differences that give rise to the net accumulated deferred income tax obligations are as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Deferred Tax Assets:
Employee Benefits	$	509.4	$	125.4	$	54.8	$	46.7	$	388.2	$	94.5	$	35.0	$	31.1
Derivative Liabilities	105.0		103.6		—		—		111.4		111.4		—		—
Regulatory Deferrals - Liabilities	267.0		37.1		165.7		19.0		299.3		38.6		195.5		16.1
Allowance for Uncollectible Accounts	56.7		25.7		17.7		2.8		54.0		23.1		17.8		3.0
Tax Effect - Tax Regulatory Liabilities	830.4		333.5		280.9		111.3		830.3		336.8		288.9		111.7
Net Operating Loss Carryforwards	9.1		—		—		—		28.5		—		—		0.6
Purchase Accounting Adjustment	58.7		—		—		—		64.2		—		—		—
Other	190.4		92.0		35.8		20.0		166.2		81.1		15.6		33.4
Total Deferred Tax Assets	2,026.7		717.3		554.9		199.8		1,942.1		685.5		552.8		195.9
Less:  Valuation Allowance	43.0		24.9		—		—		19.5		10.7		—		—
Net Deferred Tax Assets	$	1,983.7	$	692.4	$	554.9	$	199.8	$	1,922.6	$	674.8	$	552.8	$	195.9
Deferred Tax Liabilities:
Accelerated Depreciation and Other   Plant-Related Differences	$	3,901.0	$	1,362.2	$	1,391.9	$	428.9	$	3,724.2	$	1,293.3	$	1,342.4	$	410.6
Property Tax Accruals	76.8		36.8		29.0		4.7		73.2		35.4		26.3		5.2
Regulatory Amounts:
Regulatory Deferrals - Assets	1,155.6		340.7		276.2		260.9		1,025.9		320.1		277.4		213.8
Tax Effect - Tax Regulatory Assets	238.2		171.7		11.7		8.3		238.9		167.0		9.7		8.1
Goodwill Regulatory Asset - 1999 Merger	90.6		—		77.8		—		95.2		—		81.7		—
Derivative Assets	19.7		19.7		—		—		20.1		19.9		—		—
Other	257.6		5.9		125.6		3.2		251.1		5.9		109.8		39.4
Total Deferred Tax Liabilities	$	5,739.5	$	1,937.0	$	1,912.2	$	706.0	$	5,428.6	$	1,841.6	$	1,847.3	$	677.1

Summary of Tax Credits and Loss Carryforwards

The following table provides the amounts and expiration dates of state tax credit and loss carryforwards and federal tax credit and net operating loss carryforwards:

	As of December 31,
	2019									2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Expiration Range	Eversource		CL&P		NSTAR Electric		PSNH		Expiration Range
Federal Net Operating Loss	$	19.8	$	—	$	—	$	—	2033 - 2037	$	103.6	$	—	$	—	$	—	2033 - 2037
Federal Charitable Contribution	—		—		—		—		2020 - 2022	2.2		—		—		—		2020 - 2022
State Net   Operating Loss	65.5		—		—		—		2020 - 2038	80.7		—		—		—		2019 - 2038
State Tax Credit	168.1		122.3		—		—		2019 - 2024	148.9		107.0		—		—		2018 - 2023
State Charitable Contribution	9.9		—		—		—		2019 - 2023	9.6		—		—		—		2019 - 2023

Summary of Income Tax Contingencies

The amount of interest expense/(income) on uncertain tax positions recognized and the related accrued interest payable/(receivable) are as follows:  

	Other Interest Expense/(Income)							Accrued Interest Expense
	For the Years Ended December 31,							As of December 31,
(Millions of Dollars)	2019		2018			2017		2019		2018
Eversource	$	—	$	(1.7	)	$	—	$	0.1	$	0.1

 A reconciliation of the activity in unrecognized tax benefits, all of which would impact the effective tax rate if recognized, is as follows:

(Millions of Dollars)	Eversource			CL&P
Balance as of January 1, 2017	$	48.4		$	15.3
Gross Increases - Current Year	11.4			4.7
Gross Decreases - Prior Year	(0.9		)	(0.5		)
Lapse of Statute of Limitations	(7.2		)	(1.4		)
Balance as of December 31, 2017	51.7			18.1
Gross Increases - Current Year	9.2			3.2
Gross Decreases - Prior Year	(6.5		)	(0.9		)
Lapse of Statute of Limitations	(8.5		)	(2.2		)
Balance as of December 31, 2018	45.9			18.2
Gross Increases - Current Year	12.1			4.0
Gross Increases - Prior Year	3.4			3.3
Lapse of Statute of Limitations	(6.4		)	(2.4		)
Balance as of December 31, 2019	$	55.0		$	23.1

Summary of Income Tax Examinations

The following table summarizes Eversource, CL&P, NSTAR Electric and PSNH's tax years that remain subject to examination by major tax jurisdictions as of December 31, 2019:

Description	Tax Years
Federal	2019
Connecticut	2016 - 2019
Massachusetts	2016 - 2019
New Hampshire	2017 - 2019

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SCHEDULE I - FINANCIAL INFORMATION OF REGISTRANT - STATEMENTS OF INCOME (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Income Statements, Captions [Line Items]
Operating Revenues	$ 2,050,400	$ 2,175,800	$ 1,884,500	$ 2,415,800	$ 2,034,900	$ 2,271,400	$ 1,853,900	$ 2,288,000	$ 8,526,470	$ 8,448,201	$ 7,751,952
Operating Expenses:
Other									1,363,113	1,335,213	1,307,052
Operating Income	435,600	509,200	151,000	494,700	400,000	466,000	391,400	442,500	1,590,491	1,699,930	1,888,249
Interest Expense									533,197	498,805	421,755
Other Income, Net:
Equity in Earnings of Subsidiaries									42,200	3,800	27,400
Other Income, Net									132,777	128,366	107,913
Income Before Income Tax Expense									1,190,071	1,329,491	1,574,407
Income Tax Benefit									273,499	288,972	578,892
Net Income	$ 251,900	$ 320,800	$ 33,300	$ 310,600	$ 233,200	$ 291,300	$ 244,600	$ 271,400	$ 916,572	$ 1,040,519	$ 995,515
Basic Earnings Per Common Share (in dollars per share)	$ 0.77	$ 0.98	$ 0.10	$ 0.97	$ 0.73	$ 0.91	$ 0.76	$ 0.85	$ 2.83	$ 3.25	$ 3.11
Diluted Earnings Per Common Share (in dollars per share)	$ 0.76	$ 0.98	$ 0.10	$ 0.97	$ 0.73	$ 0.91	$ 0.76	$ 0.85	$ 2.81	$ 3.25	$ 3.11
Weighted Average Common Shares Outstanding:
Basic (in shares)									321,416,086	317,370,369	317,411,097
Diluted (in shares)									322,941,636	317,993,934	318,031,580
Eversource
Condensed Income Statements, Captions [Line Items]
Operating Revenues									$ 0	$ 0	$ 0
Operating Expenses:
Other									50,100	(6,552)	(32,189)
Operating Income									(50,100)	6,552	32,189
Interest Expense									163,937	123,638	80,700
Other Income, Net:
Equity in Earnings of Subsidiaries									1,001,526	1,049,748	993,063
Other, Net									68,137	47,581	23,339
Other Income, Net									1,069,663	1,097,329	1,016,402
Income Before Income Tax Expense									855,626	980,243	967,891
Income Tax Benefit									(53,427)	(52,757)	(20,105)
Net Income									$ 909,053	$ 1,033,000	$ 987,996
Basic Earnings Per Common Share (in dollars per share)									$ 2.83	$ 3.25	$ 3.11
Diluted Earnings Per Common Share (in dollars per share)									$ 2.81	$ 3.25	$ 3.11
Weighted Average Common Shares Outstanding:
Basic (in shares)									321,416,086	317,370,369	317,411,097
Diluted (in shares)									322,941,636	317,993,934	318,031,580

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RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES - Narrative (Details)	May 08, 2018 USD ($)
Debt Instrument [Line Items]
Weighted average interest rate	3.66%
PSNH | Rate Reduction Bonds
Debt Instrument [Line Items]
Amount of securitized rate reduction bonds issued	$ 635,700,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of Operating Expenses (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Summary of Accounting Policies [Line Items]
Natural gas and fuel costs	$ 462.1	$ 442.6	$ 432.5
PSNH
Summary of Accounting Policies [Line Items]
Natural gas and fuel costs	$ 0.0	$ 7.9	$ 43.4

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	$ 532.4	$ 503.2	$ 419.1
Income Taxes	56.0	158.8	30.8
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of)	379.4	389.3	379.5
CL&P
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	144.6	149.7	144.6
Income Taxes	80.6	66.1	68.8
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of)	111.3	106.1	132.5
NSTAR Electric
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	121.9	122.1	124.6
Income Taxes	77.9	120.0	95.5
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of)	116.4	116.5	116.5
PSNH
Cash Paid During the Year for:
Interest, Net of Amounts Capitalized	56.9	40.5	45.9
Income Taxes	3.4	27.3	26.1
Non-Cash Investing Activities:
Plant Additions Included in Accounts Payable (As of)	$ 49.9	$ 35.1	$ 44.4

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EMPLOYEE BENEFITS - Pension Plan Narrative (Details) - USD ($) $ in Thousands		12 Months Ended
	Dec. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Contribution Plan Disclosure [Line Items]
Liability	$ 962,510	$ 1,370,245	$ 962,510
Expected long-term rate of return		7.00%	7.00%
Compensation rate	4.00%		4.00%
CL&P
Defined Contribution Plan Disclosure [Line Items]
Liability	$ 282,771	$ 391,159	$ 282,771
PSNH
Defined Contribution Plan Disclosure [Line Items]
Liability	124,457	157,638	124,457
Pension Plan
Defined Contribution Plan Disclosure [Line Items]
Increase in liability due to amendment in pension plan	465,000	813,100
Funded status of plan	(946,100)	(1,353,100)	$ (946,100)
Expected long-term rate of return			8.25%	8.25%
Estimated future employer contributions in next fiscal year		105,000
Estimated future contributions in the next twelve months by other subsidiaries		57,300
Pension Plan | CL&P
Defined Contribution Plan Disclosure [Line Items]
Funded status of plan	(242,000)	(345,100)	$ (242,000)
Estimated future employer contributions in next fiscal year		23,200
Pension Plan | PSNH
Defined Contribution Plan Disclosure [Line Items]
Funded status of plan	(104,100)	(141,000)	(104,100)
Estimated future employer contributions in next fiscal year		19,500
Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Increase in liability due to amendment in pension plan		88,600	88,000
Funded status of plan	8,100	36,900	$ 8,100
Expected long-term rate of return			8.25%	8.25%
Estimated future employer contributions in next fiscal year		2,900
Other Postretirement Benefits Plan | CL&P
Defined Contribution Plan Disclosure [Line Items]
Funded status of plan	(41,100)	(46,400)	$ (41,100)
Other Postretirement Benefits Plan | PSNH
Defined Contribution Plan Disclosure [Line Items]
Funded status of plan	(20,700)	(17,000)	(20,700)
Other Current Liabilities
Defined Contribution Plan Disclosure [Line Items]
Funded status of plan	8,900	8,700	8,900
Other Long-Term Assets | Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Prepaid asset	33,400	62,700	33,400
Accrued Pension, SERP and PBOP | Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Liability	$ 25,300	$ 25,800	$ 25,300
Minimum | Pension Plan
Defined Contribution Plan Disclosure [Line Items]
Expected long-term rate of return		8.25%
Compensation rate	3.50%	3.50%	3.50%
Minimum | Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Expected long-term rate of return		8.25%
Maximum | Pension Plan
Defined Contribution Plan Disclosure [Line Items]
Compensation rate	4.00%	4.00%	4.00%
Pre-65 Plan | Minimum | Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Health care trend rate		3.50%
Pre-65 Plan | Minimum | Other Postretirement Benefits Plan | Aquarion
Defined Contribution Plan Disclosure [Line Items]
Health care trend rate		3.50%
Pre-65 Plan | Maximum | Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Health care trend rate		6.50%
Pre-65 Plan | Maximum | Other Postretirement Benefits Plan | Aquarion
Defined Contribution Plan Disclosure [Line Items]
Health care trend rate		6.75%
Post-65 Plan | Minimum | Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Health care trend rate		3.50%
Post-65 Plan | Minimum | Other Postretirement Benefits Plan | Aquarion
Defined Contribution Plan Disclosure [Line Items]
Health care trend rate			7.00%
Post-65 Plan | Maximum | Other Postretirement Benefits Plan
Defined Contribution Plan Disclosure [Line Items]
Health care trend rate		5.00%
Eversource Service Pension and PBOP Plans
Defined Contribution Plan Disclosure [Line Items]
Assumed rate of return		8.25%
Eversource PBOP Plan | Other Postretirement Benefits Plan | Equity Securities
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation		70.00%
Eversource PBOP Plan | Other Postretirement Benefits Plan | Fixed-Income Securities
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation		30.00%
Aquarion Plans
Defined Contribution Plan Disclosure [Line Items]
Assumed rate of return		7.00%
Aquarion Pension Plan | Pension Plan | Equity Securities
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation		54.00%
Aquarion Pension Plan | Pension Plan | Debt Securities
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation		36.00%
Aquarion Pension Plan | Pension Plan | Other Securities
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation		10.00%
Aquarion PBOP Plan | Other Postretirement Benefits Plan | Equity Securities
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation		54.00%
Aquarion PBOP Plan | Other Postretirement Benefits Plan | Debt Securities
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation		41.00%
Aquarion PBOP Plan | Other Postretirement Benefits Plan | Other Securities
Defined Contribution Plan Disclosure [Line Items]
Target Asset Allocation		5.00%

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INCOME TAXES - Reconciliation of Unrecognized Tax Benefit (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning Balance	$ 45.9	$ 51.7	$ 48.4
Gross Increases - Current Year	12.1	9.2	11.4
Gross Decreases - Prior Year		(6.5)	(0.9)
Gross Increases - Prior Year	3.4
Lapse of Statute of Limitations	(6.4)	(8.5)	(7.2)
Ending Balance	55.0	45.9	51.7
CL&P
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning Balance	18.2	18.1	15.3
Gross Increases - Current Year	4.0	3.2	4.7
Gross Decreases - Prior Year		(0.9)	(0.5)
Gross Increases - Prior Year	3.3
Lapse of Statute of Limitations	(2.4)	(2.2)	(1.4)
Ending Balance	$ 23.1	$ 18.2	$ 18.1

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INCOME TAXES - Reconciliation Between Income Tax Expense and Expected Tax Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Contingency [Line Items]
Income Before Income Tax Expense	$ 1,190,071	$ 1,329,491	$ 1,574,407
Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017	249,900	279,200	551,000
Tax Effect of Differences:
Depreciation	1,900	(30,800)	(10,800)
Investment Tax Credit Amortization	(3,700)	(2,900)	(3,200)
State Income Taxes, Net of Federal Impact	24,600	44,400	47,700
Dividends on ESOP	(5,100)	(5,100)	(8,400)
Tax Asset Valuation Allowance/Reserve Adjustments	40,100	5,200	7,000
Excess Stock Benefit	(1,500)	(1,500)	(2,900)
EDIT Amortization	(37,400)	(5,000)	0
Other, Net	4,700	5,500	(1,500)
Income Tax Expense	$ 273,499	$ 288,972	$ 578,892
Effective Tax Rate	23.00%	21.70%	36.80%
CL&P
Income Tax Contingency [Line Items]
Income Before Income Tax Expense	$ 547,823	$ 506,773	$ 563,372
Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017	115,000	106,400	197,200
Tax Effect of Differences:
Depreciation	(200)	(1,200)	(5,200)
Investment Tax Credit Amortization	(800)	(900)	(1,000)
State Income Taxes, Net of Federal Impact	2,500	14,500	4,500
Tax Asset Valuation Allowance/Reserve Adjustments	24,500	7,100	(9,500)
Excess Stock Benefit	(500)	(100)	(700)
EDIT Amortization	(5,800)	0	0
Other, Net	2,300	3,300	1,300
Income Tax Expense	$ 136,971	$ 129,056	$ 186,646
Effective Tax Rate	25.00%	25.50%	33.10%
NSTAR Electric
Income Tax Contingency [Line Items]
Income Before Income Tax Expense	$ 557,269	$ 531,996	$ 616,811
Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017	117,000	111,700	215,900
Tax Effect of Differences:
Depreciation	(3,000)	(2,800)	(3,000)
Investment Tax Credit Amortization	(2,600)	(1,800)	(1,800)
State Income Taxes, Net of Federal Impact	35,700	33,200	31,200
Tax Asset Valuation Allowance/Reserve Adjustments	0	1,200	0
Excess Stock Benefit	(500)	(100)	(700)
EDIT Amortization	(22,900)	0	0
Other, Net	1,600	7,500	500
Income Tax Expense	$ 125,313	$ 148,906	$ 242,085
Effective Tax Rate	22.50%	28.00%	39.20%
PSNH
Income Tax Contingency [Line Items]
Income Before Income Tax Expense	$ 175,023	$ 163,452	$ 224,671
Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017	36,800	34,300	78,600
Tax Effect of Differences:
Depreciation	(800)	100	1,100
Investment Tax Credit Amortization	0	0	0
State Income Taxes, Net of Federal Impact	9,800	15,800	11,300
Tax Asset Valuation Allowance/Reserve Adjustments	0	0	0
Excess Stock Benefit	(200)	(100)	(300)
EDIT Amortization	(4,000)	(4,400)	0
Other, Net	(600)	1,900	(2,000)
Income Tax Expense	$ 40,975	$ 47,576	$ 88,675
Effective Tax Rate	23.40%	29.10%	39.50%

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COMMITMENTS AND CONTINGENCIES

12 Months Ended

Dec. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES

A.     Environmental Matters

Eversource, CL&P, NSTAR Electric and PSNH are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment.  These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites. Eversource, CL&P, NSTAR Electric and PSNH have an active environmental auditing and training program and each believes it is substantially in compliance with all enacted laws and regulations.

Environmental reserves are accrued when assessments indicate it is probable that a liability has been incurred and an amount can be reasonably estimated.  The approach used estimates the liability based on the most likely action plan from a variety of available remediation options, including no action required or several different remedies ranging from establishing institutional controls to full site remediation and monitoring.  These liabilities are estimated on an undiscounted basis and do not assume that the amounts are recoverable from insurance companies or other third parties.  The environmental reserves include sites at different stages of discovery and remediation and do not include any unasserted claims.

These reserve estimates are subjective in nature as they take into consideration several different remediation options at each specific site.  The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource's, CL&P's, NSTAR Electric's and PSNH's responsibility for remediation or the extent of remediation required, recently enacted laws and regulations or changes in cost estimates due to certain economic factors. It is possible that new information or future developments could require a reassessment of the potential exposure to required environmental remediation.  As this information becomes available, management will continue to assess the potential exposure and adjust the reserves accordingly.  

The amounts recorded as environmental reserves are included in Other Current Liabilities and Other Long-Term Liabilities on the balance sheets and represent management's best estimate of the liability for environmental costs, and take into consideration site assessment, remediation and long-term monitoring costs.  The environmental reserves also take into account recurring costs of managing hazardous substances and pollutants, mandated expenditures to remediate contaminated sites and any other infrequent and non-recurring clean-up costs.  A reconciliation of the activity in the environmental reserves is as follows:

(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH
Balance as of January 1, 2018	$	54.9		$	4.7		$	2.7		$	5.7
Additions	23.5			1.9			9.7			—
Payments/Reductions	(13.7		)	(1.2		)	(1.5		)	(0.3		)
Balance as of December 31, 2018	64.7			5.4			10.9			5.4
Additions	26.5			7.0			0.5			2.8
Payments/Reductions	(10.2		)	(1.0		)	(3.4		)	(0.7		)
Balance as of December 31, 2019	$	81.0		$	11.4		$	8.0		$	7.5

The number of environmental sites for which remediation or long-term monitoring, preliminary site work or site assessment is being performed are as follows:

	Eversource	CL&P	NSTAR Electric	PSNH
2019	57	15	15	9
2018	60	15	16	9

The increase in the reserve balance was due primarily to changes in cost estimates at certain MGP sites at the natural gas companies, at CL&P and at PSNH, for which additional remediation will be required.

Included in the number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured natural gas from coal and other processes, which resulted in certain by-products remaining in the environment that may pose a potential risk to human health and the environment, for which Eversource may have potential liability.  The reserve balances related to these former MGP sites were $67.9 million and $50.1 million as of December 31, 2019 and 2018, respectively, and related primarily to the natural gas business segment.

As of December 31, 2019, for 6 environmental sites (1 for CL&P) that are included in the Company's reserve for environmental costs, the information known and the nature of the remediation options allow for the Company to estimate the range of losses for environmental costs.  As of December 31, 2019, $35.9 million (including $0.4 million for CL&P) had been accrued as a liability for these sites, which represents the low end of the range of the liabilities for environmental costs.  Management believes that additional losses of up to approximately $35 million ($0.5 million at CL&P) may be incurred in executing current remediation plans for these sites.  

As of December 31, 2019, for 15 environmental sites (7 for CL&P and 4 for NSTAR Electric) that are included in the Company's reserve for environmental costs, management cannot reasonably estimate the exposure to loss in excess of the reserve, or range of loss, as these sites are under investigation and/or there is significant uncertainty as to what remedial actions, if any, the Company may be required to undertake.  As of December 31, 2019, $7.4 million (including $2.3 million for CL&P and $1.9 million for NSTAR Electric) had been accrued as a liability for these sites.  As of December 31, 2019, for the remaining 36 environmental sites (including 7 for CL&P, 11 for NSTAR Electric and 9 for PSNH) that are included in the Company's reserve for environmental costs, the $37.7 million accrual (including $8.7 million for CL&P, $6.1 million for NSTAR Electric and $7.5 million for PSNH) represents management's best estimate of the probable liability and no additional loss is anticipated at this time.

PSNH, NSTAR Gas and Yankee Gas have rate recovery mechanisms for MGP related environmental costs, therefore, changes in their respective environmental reserves do not impact Net Income. CL&P is allowed to defer certain environmental costs for future recovery.  NSTAR Electric does not have a separate environmental cost recovery regulatory mechanism.Long-Term Contractual Arrangements

Estimated Future Annual Costs:  The estimated future annual costs of significant executed, non-cancelable, long-term contractual arrangements in effect as of December 31, 2019 are as follows:

Eversource
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	614.6	$	594.3	$	651.7	$	629.1	$	624.8	$	3,590.6	$	6,705.1
Purchased Power and Capacity	73.5		69.0		75.1		81.6		75.9		71.5		446.6
Peaker CfDs	22.4		23.0		16.9		20.1		15.5		29.8		127.7
Natural Gas Procurement	266.2		255.3		202.8		166.7		165.7		1,093.3		2,150.0
Transmission Support Commitments	22.1		—		—		—		—		—		22.1
Total	$	998.8	$	941.6	$	946.5	$	897.5	$	881.9	$	4,785.2	$	9,451.5

CL&P
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	457.3	$	459.6	$	514.4	$	516.2	517.4		2,790.6		$	5,255.5
Purchased Power and Capacity	69.8		65.3		71.4		78.0		72.9		55.5		412.9
Peaker CfDs	22.4		23.0		16.9		20.1		15.5		29.8		127.7
Transmission Support Commitments	8.7		—		—		—		—		—		8.7
Total	$	558.2	$	547.9	$	602.7	$	614.3	$	605.8	$	2,875.9	$	5,804.8

NSTAR Electric
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	95.5	$	91.2	$	91.4	$	66.6	$	63.8	$	418.1	$	826.6
Purchased Power and Capacity	3.1		3.1		3.1		3.0		3.0		16.0		31.3
Transmission Support Commitments	8.7		—		—		—		—		—		8.7
Total	$	107.3	$	94.3	$	94.5	$	69.6	$	66.8	$	434.1	$	866.6

PSNH
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	61.8	$	43.5	$	45.9	$	46.3	$	43.6	$	381.9	$	623.0
Purchased Power and Capacity	0.6		0.6		0.6		0.6		—		—		2.4
Transmission Support Commitments	4.7		—		—		—		—		—		4.7
Total	$	67.1	$	44.1	$	46.5	$	46.9	$	43.6	$	381.9	$	630.1

Renewable Energy:  Renewable energy contracts include non-cancellable commitments under contracts of CL&P, NSTAR Electric and PSNH for the purchase of energy and capacity from renewable energy facilities.  Such contracts extend through 2039 for CL&P, 2040 for NSTAR Electric and 2033 for PSNH.

On December 28, 2018, under Public Act 17-3, "An Act Concerning Zero Carbon Procurement," DEEP selected the Millstone Nuclear Power Station generation facility and Seabrook Nuclear Power Plant, along with smaller generation facilities, in DEEP’s zero-carbon request for proposal. CL&P and UI were directed by DEEP to enter into ten-year contracts to purchase a combined total of approximately 9 million MWh annually from the Millstone generation facility. On March 15, 2019, CL&P and UI each signed a ten-year contract with the owner of Millstone Nuclear Power Station in order to purchase a combined amount of approximately 50 percent of the facility's output (approximately 40 percent by CL&P). The Millstone Nuclear Power Station has a 2,112 MW nameplate capacity. PURA approved the contracts on September 18, 2019. Energy deliveries and payments under these contracts began in the fourth quarter of 2019.

CL&P and UI were also directed by DEEP to enter into eight-year contracts to purchase a combined amount of approximately 18 percent of the facility's output (approximately 15 percent by CL&P), from the Seabrook Nuclear Power Plant beginning January 1, 2022. The Seabrook Nuclear Power Plant has an approximate 1,250 MW nameplate capacity. On November 22, 2019, CL&P and UI each signed an eight-year contract with the owner of the Seabrook Nuclear Power Plant. PURA approved the contracts on November 27, 2019.

The total estimated cost of the Millstone Nuclear Power Station and Seabrook Nuclear Power Plant energy purchase contracts are $4.1 billion and are reflected in the table above. CL&P sells the energy purchased under these contracts into the market and uses the proceeds from these energy sales to offset the contract costs.  As the net costs under these contracts are recovered from customers in future rates, the contracts do not have an impact on the net income of CL&P. These new contracts do not meet the definition of a derivative, and accordingly, the costs of these contracts are being accounted for as incurred.

The contractual obligations table above does not include long-term commitments signed by CL&P and NSTAR Electric, as required by the PURA and DPU, respectively, for the purchase of renewable energy and related products that are contingent on the future construction of energy facilities.

Purchased Power and Capacity:  These contracts include capacity CfDs of CL&P through 2026, and various IPP contracts or purchase obligations for electricity which extend through 2024 for CL&P, 2031 for NSTAR Electric and 2023 for PSNH.

CL&P, along with UI, has three capacity CfDs for a total of approximately 676 MW of capacity consisting of two generation units and one demand response project.  The capacity CfDs extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set contractual capacity price and the capacity market prices received by the generation facilities in the ISO-NE capacity markets.  CL&P has a sharing agreement with UI, whereby UI shares 20 percent of the costs and benefits of these contracts.  CL&P's portion of the costs and benefits of these contracts will be paid by, or refunded to, CL&P's customers.  

The contractual obligations table above does not include CL&P's, NSTAR Electric's or PSNH's standard/basic service contracts for the purchase of energy supply, the amounts of which vary with customers' energy needs.

Peaker CfDs:  CL&P, along with UI, has three peaker CfDs for a total of approximately 500 MW of peaking capacity through 2042.  CL&P has a sharing agreement with UI, whereby CL&P is responsible for 80 percent and UI for 20 percent of the net costs or benefits of these CfDs.  The Peaker CfDs pay the generation facility owner the difference between capacity, forward reserve and energy market revenues and a cost-of-service payment stream for 30 years.  The ultimate cost or benefit to CL&P under these contracts will depend on the costs of plant operation and the prices that the projects receive for capacity and other products in the ISO-NE markets.  CL&P's portion of the amounts paid or received under the Peaker CfDs will be recoverable from, or refunded to, CL&P's customers.  

Natural Gas Procurement:  Eversource's natural gas distribution businesses have long-term contracts for the purchase, transportation and storage of natural gas as part of its portfolio of supplies, which extend through 2038.  

Transmission Support Commitments:  Along with other New England utilities, CL&P, NSTAR Electric and PSNH entered into agreements in 1985 to support transmission and terminal facilities that were built to import electricity from the Hydro-Québec system in Canada. CL&P, NSTAR Electric and PSNH are obligated to pay, over a 30-year period ending in 2020, their proportionate shares of the annual operation and maintenance expenses and capital costs of those facilities. Future transmission support agreements beginning in the second half of 2020 are under negotiation.

The total costs incurred under these agreements were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Renewable Energy	$	320.8	$	218.5	$	235.5
Purchased Power and Capacity	62.1		72.0		103.9
Peaker CfDs	13.0		20.9		38.7
Natural Gas Procurement	448.5		432.4		377.0
Transmission Support Commitments	21.8		23.4		19.8
Coal, Wood and Other (1)	—		—		47.7

	For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Renewable Energy	$	160.6	$	89.9	$	70.3	$	63.2	$	89.8	$	65.5	$	51.0	$	123.7	$	60.8
Purchased Power and Capacity	50.4		5.1		6.6		49.4		4.4		18.2		81.0		4.0		18.9
Peaker CfDs	13.0		—		—		20.9		—		—		38.7		—		—
Transmission Support Commitments	8.6		8.6		4.6		9.2		9.2		5.0		7.8		7.8		4.2
Coal, Wood and Other (1)	—		—		—		—		—		—		—		—		47.7

⁽¹⁾ PSNH previously entered into various arrangements for the purchase of coal, wood and the transportation services for fuel supply for its electric generating assets. In 2018, Eversource and PSNH completed the sales of PSNH's thermal and hydroelectric generation assets. Upon sale, the remaining future contractual obligations were transferred to the respective buyers. See Note 14, "Generation Asset Sale," for further information.Spent Nuclear Fuel Obligations - Yankee Companies

CL&P, NSTAR Electric and PSNH have plant closure and fuel storage cost obligations to the Yankee Companies, which have each completed the physical decommissioning of their respective nuclear power facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies fund these costs through litigation proceeds received from the DOE and, to the extent necessary, through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. CL&P, NSTAR Electric and PSNH, in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies collect amounts that management believes are adequate to recover the remaining plant closure and fuel storage cost estimates for the respective plants. Management believes CL&P and NSTAR Electric will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers.

Spent Nuclear Fuel Litigation:

The Yankee Companies have filed complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to accept delivery of, and provide for a permanent facility to store, spent nuclear fuel pursuant to the terms of the 1983 spent fuel and high-level waste disposal contracts between the Yankee Companies and the DOE. The court previously awarded the Yankee Companies damages for Phases I, II and III of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2012, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.

DOE Phase IV Damages - On May 22, 2017, each of the Yankee Companies filed a fourth set of lawsuits against the DOE in the Court of Federal

Claims. The Yankee Companies sought monetary damages totaling $104.4 million for CYAPC, YAEC and MYAPC, resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2013 to 2016 (“DOE Phase IV”). On February 21, 2019, the Yankee Companies received a partial summary judgment and partial final judgment in their favor for the undisputed amount of monetary damages of $103.2 million.  The court awarded CYAPC, YAEC, and MYAPC damages of $40.7 million, $28.1 million and $34.4 million, respectively. The DOE did not appeal the court's judgment and the decision became final on April 23, 2019. On June 12, 2019, each of the Yankee Companies received the damages proceeds. On June 12, 2019, the court accepted an offer of judgment in the amount of $0.5 million to settle the disputed amount of approximately $1 million in Phase IV contested damages. The Yankee Companies received the $0.5 million payment in July 2019. CYAPC's and YAEC's proceeds received were classified as operating activities on the Eversource consolidated statement of cash flows.

In September 2019, the Yankee Companies made a required informational filing with FERC as to the use of proceeds, for which approval was received in the fourth quarter of 2019. In December 2019, YAEC and MYAPC returned proceeds of $5.4 million and $21.0 million, respectively, to its member companies, of which the Eversource utilities (CL&P, NSTAR Electric and PSNH) received a total of $2.8 million from YAEC and $5.0 million from MYAPC. The Eversource utilities will ultimately refund these proceeds to utility customers. Also, in December 2019, CYAPC paid $29.0 million to the DOE to partially settle its pre-1983 spent nuclear fuel obligation.Guarantees and Indemnifications

In the normal course of business, Eversource parent provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric and PSNH, in the form of guarantees. Management does not anticipate a material impact to net income or cash flows as a result of these various guarantees and indemnifications.  The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries and affiliates to external parties as of December 31, 2019:

Company	Description	Maximum Exposure (in millions)		Expiration Dates
Various	Surety Bonds (1)	$	29.2	2020 - 2021
Rocky River Realty Company and Eversource Service	Lease Payments for Real Estate	6.5		2024
Bay State Wind LLC	Real Estate Purchase	2.5		2020
Sunrise Wind LLC	Offshore Wind (2)	2.2		—

⁽¹⁾  Surety bond expiration dates reflect termination dates, the majority of which will be renewed or extended.  Certain surety bonds contain credit ratings triggers that would require Eversource parent to post collateral in the event that the unsecured debt credit ratings of Eversource parent are downgraded.  

⁽²⁾  On October 25, 2019, Eversource parent issued a guaranty on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guaranty Sunrise Wind LLC's performance of certain obligations, in an amount not to exceed $15.4 million, under the Offshore Wind Renewable Energy Certificate Purchase and Sale Agreement (the Agreement). The Agreement was executed on October 25, 2019, by and between NYSERDA and Sunrise Wind LLC. Obligations of Eversource parent under the guaranty expire at such time as the guaranteed obligations have been fully performed. The Company regularly reviews performance risk under this arrangement, and in the event it becomes probable that Eversource parent will be required to perform under the guarantee, the amount of probable payment will be recorded. As of December 31, 2019, the fair value of the guarantee was immaterial.

Eversource parent issued a guaranty on behalf of its subsidiary, NPT, under which, beginning at the time the Northern Pass Transmission line would go into commercial operation, Eversource parent would guarantee the financial obligations of NPT under the TSA with HQ in an amount not to exceed $25 million.  Eversource parent's obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations. In the second quarter of 2019, Eversource concluded that construction of the NPT project was no longer probable. For further information regarding the impairment of NPT, see Note 1D, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements. While this guaranty is currently outstanding, it is expected to be extinguished in connection with the final dissolution of NPT.

FERC ROE Complaints

Four separate complaints were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively, the Complainants). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive (incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, the FERC set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the Court).

All amounts associated with the first complaint period have been refunded, which totaled $38.9 million (pre-tax and excluding interest) at Eversource and reflected both the base ROE and incentive cap prescribed by the FERC order. The refund consisted of $22.4 million for CL&P, $13.7 million for NSTAR Electric and $2.8 million for PSNH.

Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of December 31, 2019. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of December 31, 2019.

On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.

The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.

If the results of the illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order.

On November 21, 2019, FERC issued an order concerning the transmission ROEs for the Midcontinent ISO transmission owners (MISO). In that order, FERC adopted another new methodology for determining base ROEs for MISO, which differed significantly from the methodology and framework set forth in its October 16, 2018 FERC order on the NETOs’ ROE dockets. On December 23, 2019, the NETOs filed a Supplemental Paper Hearing Brief and a Motion to supplement the record in the NETO ROE dockets to respond to the new methodology proposed in the MISO order, as there is uncertainty to whether it may be applied to the NETOs’ cases. On January 21, 2020, the FERC issued an order granting rehearing for further consideration to give the FERC more time to act on the substantive issues of the MISO ROE proceedings. Further changes to the methodology by FERC are possible as a result of the arguments in both the MISO and NETO proceedings. Given the significant uncertainty relating to the October 2018 FERC order, the November 2019 FERC order to MISO, and the FERC's rehearing of the MISO order, the Company is unable to predict the potential effect of the MISO order on the NETO complaints or the outcome of the four complaints and concluded that there is

no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods at this time. Further, the Company cannot reasonably estimate a range of gain or loss for any of the four complaint proceedings.

Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.

A change of 10 basis points to the base ROE used to establish the reserves would impact Eversource’s after-tax earnings by an average of approximately $3 million for each of the four 15-month complaint periods.

F.    Eversource and NSTAR Electric Boston Harbor Civil Action

On July 15, 2016, the United States Attorney on behalf of the United States Army Corps of Engineers filed a civil action in the United States District Court for the District of Massachusetts under provisions of the Rivers and Harbors Act of 1899 and the Clean Water Act against NSTAR Electric, HEEC, and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the Defendants).  The action alleged that the Defendants failed to comply with certain permitting requirements related to the placement of the HEEC-owned electric distribution cable beneath Boston Harbor.  The action sought an order to compel HEEC to comply with cable depth requirements in the United States Army Corps of Engineers' permit or alternatively to remove the electric distribution cable and cease unauthorized work in U.S. waterways.  The action also sought civil penalties and other costs.

The parties reached a settlement pursuant to which HEEC agreed to install a new 115kV distribution cable across Boston Harbor to Deer Island, utilizing a different route, and remove portions of the existing cable. Upon the installation and completion of the new cable and the removal of the portions of the existing cable, all issues surrounding the current permit from the United States Army Corps of Engineers are expected to be resolved, and such litigation is expected to be dismissed with prejudice. Construction of the new distribution cable was completed in August 2019 and removal of the portions of the existing cable was completed in January 2020.

NSTAR Electric agreed to provide a rate base credit of $17.5 million to the Massachusetts Water Resources Authority for the new cable. This negotiated credit resulted in the initial $17.5 million of construction costs on the new cable being expensed as incurred, all of which was fully expensed in 2018. In connection with the new cable that was placed into service, a corresponding ARO was recognized for approximately $32 million within Other Long-Term Liabilities on the Eversource and NSTAR Electric balance sheets as of December 31, 2019.  For further information on the ARO, see Note 7, "Asset Retirement Obligations," to the financial statements.

G.     Litigation and Legal Proceedings

Eversource, including CL&P, NSTAR Electric and PSNH, are involved in legal, tax and regulatory proceedings regarding matters arising in the ordinary course of business, which involve management's assessment to determine the probability of whether a loss will occur and, if probable, its best estimate of probable loss.  The Company records and discloses losses when these losses are probable and reasonably estimable, and discloses matters when losses are probable but not estimable or when losses are reasonably possible.  Legal costs related to the defense of loss contingencies are expensed as incurred.

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GENERATION ASSET SALE - Narrative (Details) - USD ($)				12 Months Ended
	Nov. 27, 2019	Aug. 26, 2018	Jan. 10, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	May 08, 2018
Regulatory Assets [Line Items]
Proceeds from the sale of thermal assets				$ 0	$ 193,924,000	$ 0
Securitized Stranded Cost (included in Regulatory Assets)				5,514,700,000	5,145,900,000
Recoverable Divestiture Related Costs	$ 654,000,000.0
Pre-tax incmoe associated with generation assets				1,190,071,000	1,329,491,000	1,574,407,000
PSNH
Regulatory Assets [Line Items]
Purchase price in purchase sale agreement for thermal generation assets			$ 175,000,000
Proceeds from the sale of thermal assets			116,800,000	0	193,924,000	0
Purchase price in purchase sale agreement for hydroelectric assets		$ 5,800,000	$ 83,000,000
Proceeds from assets held for sale		77,200,000
Gain in sale of proceeds		17,300,000
Securitized Stranded Cost (included in Regulatory Assets)				945,800,000	929,500,000
Pre-tax incmoe associated with generation assets				175,023,000	163,452,000	224,671,000
Domestic Tax Authority | PSNH
Regulatory Assets [Line Items]
Pre-tax incmoe associated with generation assets		$ 9,900,000				$ 60,000,000.0
Rate Reduction Bonds | PSNH
Regulatory Assets [Line Items]
Amount of securitized rate reduction bonds issued							$ 635,700,000
Securitized Stranded Costs
Regulatory Assets [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)				565,300,000	608,400,000
Securitized Stranded Costs | PSNH
Regulatory Assets [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)				565,300,000	608,400,000
Variable Interest Entity, Primary Beneficiary | Securitized Stranded Costs | PSNH
Regulatory Assets [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)				$ 565,300,000	$ 608,400,000

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LEASES - Supplemental Balance Sheet Information Related to Leases (Details) $ in Millions	Dec. 31, 2019 USD ($)
Operating Leases:
Operating Lease Right-of-use-Assets, Net	$ 49.9
Operating Lease Liabilities - Current Portion	8.6
Operating Lease Liabilities - Long-Term	41.3
Total Operating Lease Liabilities	49.9
Finance Leases:
Finance Lease Right-of-use-Assets, Net	8.2
Finance Lease Liabilities - Current Portion	2.4
Finance Lease Liabilities - Long-Term	8.1
Total Finance Lease Liabilities	10.5
CL&P
Operating Leases:
Operating Lease Right-of-use-Assets, Net	0.7
Operating Lease Liabilities - Current Portion	0.5
Operating Lease Liabilities - Long-Term	0.2
Total Operating Lease Liabilities	0.7
Finance Leases:
Finance Lease Right-of-use-Assets, Net	1.9
Finance Lease Liabilities - Current Portion	1.6
Finance Lease Liabilities - Long-Term	1.4
Total Finance Lease Liabilities	3.0
NSTAR Electric
Operating Leases:
Operating Lease Right-of-use-Assets, Net	24.2
Operating Lease Liabilities - Current Portion	0.7
Operating Lease Liabilities - Long-Term	23.5
Total Operating Lease Liabilities	24.2
Finance Leases:
Finance Lease Right-of-use-Assets, Net	3.3
Finance Lease Liabilities - Current Portion	0.0
Finance Lease Liabilities - Long-Term	4.4
Total Finance Lease Liabilities	4.4
PSNH
Operating Leases:
Operating Lease Right-of-use-Assets, Net	0.4
Operating Lease Liabilities - Current Portion	0.1
Operating Lease Liabilities - Long-Term	0.3
Total Operating Lease Liabilities	0.4
Finance Leases:
Finance Lease Right-of-use-Assets, Net	0.9
Finance Lease Liabilities - Current Portion	0.1
Finance Lease Liabilities - Long-Term	0.8
Total Finance Lease Liabilities	$ 0.9

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ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

12 Months Ended

Dec. 31, 2019

Equity [Abstract]

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

The changes in accumulated other comprehensive income/(loss) by component, net of tax, are as follows:

	For the Year Ended December 31, 2019												For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Qualified Cash Flow Hedging Instruments			Unrealized Gains/(Losses) on Marketable Securities			Defined Benefit Plans			Total			Qualified Cash Flow Hedging Instruments			Unrealized Losses on Marketable Securities			Defined Benefit Plans			Total
Balance as of January 1st	$	(4.4	)	$	(0.5	)	$	(55.1	)	$	(60.0	)	$	(6.2	)	$	—		$	(60.2	)	$	(66.4	)
OCI Before Reclassifications	—			1.2			(13.3		)	(12.1		)	—			(0.5		)	0.3			(0.2		)
Amounts Reclassified from AOCI	1.4			—			5.6			7.0			1.8			—			4.8			6.6
Net OCI	1.4			1.2			(7.7		)	(5.1		)	1.8			(0.5		)	5.1			6.4
Balance as of December 31st	$	(3.0	)	$	0.7		$	(62.8	)	$	(65.1	)	$	(4.4	)	$	(0.5	)	$	(55.1	)	$	(60.0	)

Eversource's qualified cash flow hedging instruments represent interest rate swap agreements on debt issuances that were settled in prior years. The settlement amount was recorded in AOCI and is being amortized into Net Income over the term of the underlying debt instrument.  CL&P, NSTAR Electric and PSNH continue to amortize interest rate swaps settled in prior years from AOCI into Interest Expense over the remaining life of the associated long-term debt. Such interest rate swaps are not material to their respective financial statements.

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses that arose during the year and were recognized in AOCI. The unamortized actuarial gains and losses and prior service costs on the defined benefit plans are amortized from AOCI into Other Income, Net over the average future employee service period, and are reflected in amounts reclassified from AOCI. The related tax effects recognized in AOCI were net deferred tax assets of $4.4 million and $4.1 million in 2019 and 2017, respectively, and deferred tax liabilities of $0.2 million in 2018.

Eversource did not elect to reclassify the income tax effects of the Tax Cuts and Jobs Act from AOCI to Retained Earnings as permitted by ASU 2018-02, Income Statement – Reporting Comprehensive Income (Topic 220).

The following table sets forth the amounts reclassified from AOCI by component and the impacted line item on the statements of income:

	Amounts Reclassified from AOCI
Eversource (Millions of Dollars)	For the Years Ended December 31,									Statements of Income Line Item Impacted
	2019			2018			2017
Qualified Cash Flow Hedging Instruments	$	(2.5	)	$	(2.8	)	$	(3.3	)	Interest Expense
Tax Effect	1.1			1.0			1.3			Income Tax Expense
Qualified Cash Flow Hedging Instruments, Net of Tax	$	(1.4	)	$	(1.8	)	$	(2.0	)
Defined Benefit Plan Costs:
Amortization of Actuarial Losses	$	(5.7	)	$	(6.0	)	$	(6.2	)	Other Income, Net (1)
Amortization of Prior Service Cost	(1.8		)	(0.4		)	(1.1		)	Other Income, Net (1)
Total Defined Benefit Plan Costs	(7.5		)	(6.4		)	(7.3		)
Tax Effect	1.9			1.6			2.8			Income Tax Expense
Defined Benefit Plan Costs, Net of Tax	$	(5.6	)	$	(4.8	)	$	(4.5	)
Total Amounts Reclassified from AOCI, Net of Tax	$	(7.0	)	$	(6.6	)	$	(6.5	)

⁽¹⁾  These amounts are included in the computation of net periodic Pension, SERP and PBOP costs.  See Note 1M, "Summary of Significant Accounting Policies – Other Income, Net" and Note 11A, "Employee Benefits – Pension Benefits and Postretirement Benefits Other Than Pension," for further information.

As of December 31, 2019, it is estimated that a pre-tax amount of $2.5 million ($0.7 million for NSTAR Electric and $1.8 million for PSNH) will be reclassified from AOCI as a decrease to Net Income over the next 12 months as a result of the amortization of the interest rate swap agreements which have been settled.  In addition, it is estimated that a pre-tax amount of $7.8 million will be reclassified from AOCI as a decrease to Net Income over the next 12 months as a result of the amortization of Pension, SERP and PBOP costs.

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COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

12 Months Ended

Dec. 31, 2019

Equity [Abstract]

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

COMMON SHARES

The following table sets forth the Eversource parent common shares and the shares of common stock of CL&P, NSTAR Electric and PSNH that were authorized and issued, as well as the respective per share par values:  

	Shares
	Par Value		Authorized as of December 31, 2019 and 2018	Issued as of December 31,
				2019	2018
Eversource	$	5	380,000,000	345,858,402	333,878,402
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

Common Share Issuance and Forward Sale Agreement: On June 4, 2019, Eversource completed an equity offering of 17,940,000 common shares, consisting of 5,980,000 common shares issued directly by the Company and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resulted in proceeds of $426.9 million, net of issuance costs.

Under the forward sale agreement, a total of 11,960,000 common shares were borrowed from third parties and sold by the underwriters. The forward sale agreement allows Eversource, at its election and prior to May 29, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially, $71.48 per share) or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as dividends.

On December 30, 2019, Eversource physically settled a portion of the forward sale agreement by delivering 6,000,000 common shares in exchange for net proceeds of $425.4 million. The forward sale price used to determine the cash proceeds received by Eversource was calculated based on the initial forward sale price of $71.48 per share, as adjusted in accordance with the forward sale agreement.

The 2019 issuances of 11,980,000 common shares resulted in proceeds of $852.3 million, net of issuance costs, and were reflected in shareholders’ equity and as financing activities on the statement of cash flows.

Eversource’s intent is to physically settle the forward sale agreement by issuing common shares. As of December 31, 2019, if Eversource had elected to net settle the forward sale agreement, Eversource would have been required to pay $84.4 million under a cash settlement or would have been required to deliver 992,189 common shares under a net share settlement.

Issuances of shares under the forward sale agreement are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreement have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method. See Note 22, "Earnings Per Share," to the financial statements for information on the forward sale agreement’s impact on the calculation of diluted EPS.

Eversource used the net proceeds received upon the direct issuance of common shares and the net proceeds received upon partial settlement of the forward sale agreement to repay short-term debt under the commercial paper program, to fund capital spending and clean energy initiatives, and for general corporate purposes.

Treasury Shares: As of December 31, 2019 and 2018, there were 15,977,757 and 16,992,594 Eversource common shares held as treasury shares, respectively.  As of December 31, 2019 and 2018, there were 329,880,645 and 316,885,808 Eversource common shares outstanding, respectively.

Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan.

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $7.5 million for each of the years ended December 31, 2019, 2018 and 2017.  These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of December 31, 2019 and 2018.  On the Eversource balance sheets, Common Shareholders' Equity was fully attributable to Eversource parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.

For the years ended December 31, 2019, 2018 and 2017, there was no change in ownership of the common equity of CL&P and NSTAR Electric.

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LEASES - Future Minimum Rental Payments under Capital Leases (Details) $ in Millions	Dec. 31, 2018 USD ($)
Capital Leased Assets [Line Items]
2019	$ 3.4
2020	3.4
2021	2.9
2022	1.5
2023	0.7
Thereafter	13.9
Future minimum lease payments	25.8
Less amount representing interest	13.8
Present value of future minimum lease payments	12.0
CL&P
Capital Leased Assets [Line Items]
2019	2.0
2020	2.0
2021	1.5
2022	0.0
2023	0.0
Thereafter	0.0
Future minimum lease payments	5.5
Less amount representing interest	1.0
Present value of future minimum lease payments	4.5
NSTAR Electric
Capital Leased Assets [Line Items]
2019	0.5
2020	0.5
2021	0.5
2022	0.6
2023	0.6
Thereafter	13.4
Future minimum lease payments	16.1
Less amount representing interest	12.4
Present value of future minimum lease payments	3.7
PSNH
Capital Leased Assets [Line Items]
2019	0.1
2020	0.1
2021	0.1
2022	0.1
2023	0.1
Thereafter	0.5
Future minimum lease payments	1.0
Less amount representing interest	0.1
Present value of future minimum lease payments	$ 0.9

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COMMITMENTS AND CONTINGENCIES (Tables)

12 Months Ended

Dec. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

Schedule of Environmental Loss Contingencies by Site

A reconciliation of the activity in the environmental reserves is as follows:

(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH
Balance as of January 1, 2018	$	54.9		$	4.7		$	2.7		$	5.7
Additions	23.5			1.9			9.7			—
Payments/Reductions	(13.7		)	(1.2		)	(1.5		)	(0.3		)
Balance as of December 31, 2018	64.7			5.4			10.9			5.4
Additions	26.5			7.0			0.5			2.8
Payments/Reductions	(10.2		)	(1.0		)	(3.4		)	(0.7		)
Balance as of December 31, 2019	$	81.0		$	11.4		$	8.0		$	7.5

The number of environmental sites for which remediation or long-term monitoring, preliminary site work or site assessment is being performed are as follows:

	Eversource	CL&P	NSTAR Electric	PSNH
2019	57	15	15	9
2018	60	15	16	9

Schedule of Estimated Future Annual Costs of Long term Contractual Agreement

The estimated future annual costs of significant executed, non-cancelable, long-term contractual arrangements in effect as of December 31, 2019 are as follows:

Eversource
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	614.6	$	594.3	$	651.7	$	629.1	$	624.8	$	3,590.6	$	6,705.1
Purchased Power and Capacity	73.5		69.0		75.1		81.6		75.9		71.5		446.6
Peaker CfDs	22.4		23.0		16.9		20.1		15.5		29.8		127.7
Natural Gas Procurement	266.2		255.3		202.8		166.7		165.7		1,093.3		2,150.0
Transmission Support Commitments	22.1		—		—		—		—		—		22.1
Total	$	998.8	$	941.6	$	946.5	$	897.5	$	881.9	$	4,785.2	$	9,451.5

CL&P
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	457.3	$	459.6	$	514.4	$	516.2	517.4		2,790.6		$	5,255.5
Purchased Power and Capacity	69.8		65.3		71.4		78.0		72.9		55.5		412.9
Peaker CfDs	22.4		23.0		16.9		20.1		15.5		29.8		127.7
Transmission Support Commitments	8.7		—		—		—		—		—		8.7
Total	$	558.2	$	547.9	$	602.7	$	614.3	$	605.8	$	2,875.9	$	5,804.8

NSTAR Electric
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	95.5	$	91.2	$	91.4	$	66.6	$	63.8	$	418.1	$	826.6
Purchased Power and Capacity	3.1		3.1		3.1		3.0		3.0		16.0		31.3
Transmission Support Commitments	8.7		—		—		—		—		—		8.7
Total	$	107.3	$	94.3	$	94.5	$	69.6	$	66.8	$	434.1	$	866.6

PSNH
(Millions of Dollars)	2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	61.8	$	43.5	$	45.9	$	46.3	$	43.6	$	381.9	$	623.0
Purchased Power and Capacity	0.6		0.6		0.6		0.6		—		—		2.4
Transmission Support Commitments	4.7		—		—		—		—		—		4.7
Total	$	67.1	$	44.1	$	46.5	$	46.9	$	43.6	$	381.9	$	630.1

The total costs incurred under these agreements were as follows:

Eversource	For the Years Ended December 31,
(Millions of Dollars)	2019		2018		2017
Renewable Energy	$	320.8	$	218.5	$	235.5
Purchased Power and Capacity	62.1		72.0		103.9
Peaker CfDs	13.0		20.9		38.7
Natural Gas Procurement	448.5		432.4		377.0
Transmission Support Commitments	21.8		23.4		19.8
Coal, Wood and Other (1)	—		—		47.7

	For the Years Ended December 31,
	2019						2018						2017
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Renewable Energy	$	160.6	$	89.9	$	70.3	$	63.2	$	89.8	$	65.5	$	51.0	$	123.7	$	60.8
Purchased Power and Capacity	50.4		5.1		6.6		49.4		4.4		18.2		81.0		4.0		18.9
Peaker CfDs	13.0		—		—		20.9		—		—		38.7		—		—
Transmission Support Commitments	8.6		8.6		4.6		9.2		9.2		5.0		7.8		7.8		4.2
Coal, Wood and Other (1)	—		—		—		—		—		—		—		—		47.7

⁽¹⁾ PSNH previously entered into various arrangements for the purchase of coal, wood and the transportation services for fuel supply for its electric generating assets. In 2018, Eversource and PSNH completed the sales of PSNH's thermal and hydroelectric generation assets. Upon sale, the remaining future contractual obligations were transferred to the respective buyers. See Note 14, "Generation Asset Sale," for further information.

Schedule of Guarantor Obligations

The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries and affiliates to external parties as of December 31, 2019:

Company	Description	Maximum Exposure (in millions)		Expiration Dates
Various	Surety Bonds (1)	$	29.2	2020 - 2021
Rocky River Realty Company and Eversource Service	Lease Payments for Real Estate	6.5		2024
Bay State Wind LLC	Real Estate Purchase	2.5		2020
Sunrise Wind LLC	Offshore Wind (2)	2.2		—

⁽¹⁾  Surety bond expiration dates reflect termination dates, the majority of which will be renewed or extended.  Certain surety bonds contain credit ratings triggers that would require Eversource parent to post collateral in the event that the unsecured debt credit ratings of Eversource parent are downgraded.  

⁽²⁾ 

On October 25, 2019, Eversource parent issued a guaranty on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guaranty Sunrise Wind LLC's performance of certain obligations, in an amount not to exceed $15.4 million, under the Offshore Wind Renewable Energy Certificate Purchase and Sale Agreement (the Agreement). The Agreement was executed on October 25, 2019, by and between NYSERDA and Sunrise Wind LLC. Obligations of Eversource parent under the guaranty expire at such time as the guaranteed obligations have been fully performed. The Company regularly reviews performance risk under this arrangement, and in the event it becomes probable that Eversource parent will be required to perform under the guarantee, the amount of probable payment will be recorded. As of December 31, 2019, the fair value of the guarantee was immaterial

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SCHEDULE I - FINANCIAL INFORMATION OF REGISTRANT - STATEMENTS OF COMPREHENSIVE INCOME (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Statement of Income Captions [Line Items]
Net Income	$ 251,900	$ 320,800	$ 33,300	$ 310,600	$ 233,200	$ 291,300	$ 244,600	$ 271,400	$ 916,572	$ 1,040,519	$ 995,515
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments									1,393	1,756	1,974
Changes in Unrealized Gains/(Losses) on Marketable Securities									1,166	(547)	(350)
Change in Funded Status of Pension, SERP and PBOP Benefit Plans									(7,618)	5,194	(2,745)
Other Comprehensive (Loss)/Income, Net of Tax									(5,059)	6,403	(1,121)
Comprehensive Income Attributable to Common Shareholders									903,994	1,039,403	986,875
Eversource
Condensed Statement of Income Captions [Line Items]
Net Income									909,053	1,033,000	987,996
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments									1,393	1,756	1,974
Changes in Unrealized Gains/(Losses) on Marketable Securities									1,166	(547)	(350)
Change in Funded Status of Pension, SERP and PBOP Benefit Plans									(7,618)	5,194	(2,745)
Other Comprehensive (Loss)/Income, Net of Tax									(5,059)	6,403	(1,121)
Comprehensive Income Attributable to Common Shareholders									$ 903,994	$ 1,039,403	$ 986,875

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ACQUISITION OF AQUARION AND GOODWILL - Schedule of Goodwill by Reportable Segments (Details) $ in Billions	12 Months Ended
	Dec. 31, 2019 USD ($)
Business Acquisition [Line Items]
Goodwill	$ 4.4
Electric Distribution
Business Acquisition [Line Items]
Goodwill	2.5
Electric Transmission
Business Acquisition [Line Items]
Goodwill	0.6
Natural Gas Distribution
Business Acquisition [Line Items]
Goodwill	0.4
Water Distribution
Business Acquisition [Line Items]
Goodwill	$ 0.9

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LONG-TERM DEBT (Tables)

12 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]

Schedule of Outstanding Long-Term Debt

The amount of borrowings outstanding and available under the commercial paper programs were as follows:

	Borrowings Outstanding  as of December 31,				Available Borrowing Capacity as of December 31,				Weighted-Average Interest Rate as of December 31,
(Millions of Dollars)	2019		2018		2019		2018		2019		2018
Eversource Parent Commercial Paper Program	$	1,224.9	$	631.5	$	225.1	$	818.5	1.98	%	2.77	%
NSTAR Electric Commercial Paper Program	10.5		278.5		639.5		371.5		1.63	%	2.50	%

Details of long-term debt outstanding are as follows:

CL&P (Millions of Dollars)	As of December 31,
	2019			2018
First Mortgage Bonds:
7.875% 1994 Series D due 2024	$	139.8		$	139.8
5.750% 2004 Series B due 2034	130.0			130.0
5.625% 2005 Series B due 2035	100.0			100.0
6.350% 2006 Series A due 2036	250.0			250.0
5.750% 2007 Series B due 2037	150.0			150.0
6.375% 2007 Series D due 2037	100.0			100.0
5.500% 2009 Series A due 2019	—			250.0
2.500% 2013 Series A due 2023	400.0			400.0
4.300% 2014 Series A due 2044	475.0			475.0
4.150% 2015 Series A due 2045	350.0			350.0
3.200% 2017 Series A due 2027	500.0			300.0
4.000% 2018 Series A due 2048	800.0			500.0
Total First Mortgage Bonds	3,394.8			3,144.8
Pollution Control Revenue Bonds:
4.375% Fixed Rate Tax Exempt due 2028	120.5			120.5
Less Amounts due Within One Year	—			(250.0		)
Unamortized Premiums and Discounts, Net	27.8			10.2
Unamortized Debt Issuance Costs	(25.0		)	(21.5		)
CL&P Long-Term Debt	$	3,518.1		$	3,004.0

NSTAR Electric (Millions of Dollars)	As of December 31,
	2019			2018
Debentures:
5.750% due 2036	$	200.0		$	200.0
5.500% due 2040	300.0			300.0
2.375% due 2022	400.0			400.0
4.400% due 2044	300.0			300.0
3.250% due 2025	250.0			250.0
2.700% due 2026	250.0			250.0
3.200% due 2027	700.0			700.0
3.250% due 2029	400.0			—
Total Debentures	2,800.0			2,400.0
Notes:
5.900% Senior Notes Series B due 2034	50.0			50.0
6.700% Senior Notes Series D due 2037	40.0			40.0
5.100% Senior Notes Series E due 2020	95.0			95.0
3.500% Senior Notes Series F due 2021	250.0			250.0
3.880% Senior Notes Series G due 2023	80.0			80.0
2.750% Senior Notes Series H due 2026	50.0			50.0
Total Notes	565.0			565.0
Less Amounts due Within One Year	(95.0		)	—
Unamortized Premiums and Discounts, Net	(4.1		)	(2.5		)
Unamortized Debt Issuance Costs	(18.8		)	(17.7		)
NSTAR Electric Long-Term Debt	$	3,247.1		$	2,944.8

PSNH (Millions of Dollars)	As of December 31,
	2019			2018
First Mortgage Bonds:
5.600% Series M due 2035	$	50.0		$	50.0
4.500% Series P due 2019	—			150.0
4.050% Series Q due 2021	122.0			122.0
3.200% Series R due 2021	160.0			160.0
3.500% Series S due 2023	325.0			325.0
3.600% Series T due 2049	300.0			—
Total First Mortgage Bonds	957.0			807.0
Less Amounts due Within One Year	—			(150.0		)
Unamortized Premiums and Discounts, Net	(0.7		)	—
Unamortized Debt Issuance Costs	(4.7		)	(1.8		)
PSNH Long-Term Debt	$	951.6		$	655.2

OTHER (Millions of Dollars)	As of December 31,
	2019			2018
Yankee Gas - First Mortgage Bonds: 2.230% - 8.480% due 2020 - 2049	$	620.0		$	470.0
NSTAR Gas - First Mortgage Bonds: 3.740% - 9.950% due 2020 - 2049	460.0			385.0
Aquarion - Senior Note 4.000% due 2024	360.0			360.0
Aquarion - Unsecured Notes 0% - 6.430% due 2021 - 2049	335.3			289.5
Aquarion - Secured Debt 4.100% - 9.640% due 2021 - 2035	68.8			70.7
Eversource Parent - Debentures 4.500% due 2019	—			350.0
Eversource Parent - Senior Notes 2.500% - 4.250% due 2021 - 2029	4,000.0			4,000.0
Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)	11.6			39.5
Fair Value Adjustment (1)	109.1			144.7
Less Fair Value Adjustment - Current Portion (1)	(31.3		)	(36.2		)
Less Amounts due in One Year	(201.1		)	(401.1		)
Commercial Paper Classified as Long-Term Debt (See Note 8, Short-Term Debt)	346.3			—
Unamortized Premiums and Discounts, Net	(4.1		)	(4.2		)
Unamortized Debt Issuance Costs	(20.6		)	(23.2		)
Total Other Long-Term Debt	$	6,054.0		$	5,644.7
Total Eversource Long-Term Debt	$	13,770.8		$	12,248.7

⁽¹⁾ The fair value adjustment amount is the purchase price adjustments, net of amortization, required to record long-term debt at fair value on the dates of the 2012 merger with NSTAR and the 2017 acquisition of Aquarion.

Schedule of Issuance and Repayments of Long-term Debt

The following table summarizes long-term debt issuances and repayments:

(Millions of Dollars)	Issue Date	Issuance/(Repayment)			Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P:
4.00% 2018 Series A First Mortgage Bonds (1)	April 2019	$	300.0		April 2048	Paid short-term borrowings that were used to pay long-term debt that matured on February 1, 2019 and fund capital expenditures and working capital
3.20% 2017 Series A First Mortgage Bonds (2)	September 2019	200.0			March 2027	Paid short-term borrowings and fund capital expenditures and working capital
5.50% 2009 Series A First Mortgage Bonds	February 2009	(250.0		)	February 2019	Paid at maturity on February 1, 2019
NSTAR Electric:
3.25% 2019 Debentures	May 2019	400.0			May 2029	Paid short-term borrowings that were used to fund investments in eligible green expenditures
PSNH:
3.60% 2019 Series T First Mortgage Bonds	June 2019	300.0			July 2049	Paid long-term debt that matured in December 2019, paid short-term borrowings and fund capital expenditures and working capital
4.50% 2009 Series P First Mortgage Bonds	December 2009	(150.0		)	December 2019	Paid at maturity on December 1, 2019
Other:
Eversource Parent 4.50% Debentures	November 2009	(350.0		)	November 2019	Paid at maturity on November 15, 2019
Eversource Parent 3.45% Series P Senior Notes	January 2020	350.0			January 2050	Paid short-term borrowings
NSTAR Gas 3.74% Series Q First Mortgage Bonds	July 2019	75.0			August 2049	Paid short-term borrowings and fund capital expenditures and working capital
Yankee Gas 2.23% Series P First Mortgage Bonds	September 2019	100.0			October 2024	Paid short-term borrowings and for general corporate purposes
Yankee Gas 3.30% Series Q First Mortgage Bonds	September 2019	100.0			October 2049	Paid short-term borrowings and for general corporate purposes
Yankee Gas 5.26% Series H First Mortgage Bonds	November 2004	(50.0		)	November 2019	Paid at maturity on November 1, 2019
Aquarion 3.54% Senior Notes	December 2019	45.0			December 2049	Paid short-term borrowings

⁽¹⁾ These bonds are part of the same series issued by CL&P in March 2018. The aggregate outstanding principal amount of these bonds is now $800 million.

⁽²⁾ These bonds are part of the same series issued by CL&P in March 2017. The aggregate outstanding principal amount of these bonds is now $500 million.

Schedule of Maturities of Long-term Debt Outstanding

Long-term debt maturities on debt outstanding for the years 2020 through 2024 and thereafter are shown below. These amounts exclude PSNH rate reduction bonds, CYAPC pre-1983 spent nuclear fuel obligation, net unamortized premiums, discounts and debt issuance costs, and other fair value adjustments as of December 31, 2019:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2020	$	296.1	$	—	$	95.0	$	—
2021	1,033.6		—		250.0		282.0
2022	1,188.9		—		400.0		—
2023	1,665.2		400.0		80.0		325.0
2024	1,049.8		139.8		—		—
Thereafter	8,447.8		2,975.5		2,540.0		350.0
Total	$	13,681.4	$	3,515.3	$	3,365.0	$	957.0

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MARKETABLE SECURITIES (Tables)

12 Months Ended

Dec. 31, 2019

Investments, Debt and Equity Securities [Abstract]

Schedule of Available-for-sale Securities Reconciliation

The following is a summary of the available-for-sale debt securities, which are recorded at fair value and are included in current and long-term Marketable Securities on the balance sheets.

	As of December 31,
	2019									2018
Eversource (Millions of Dollars)	Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value
Debt Securities	$	228.4	$	5.8	$	(0.1	)	$	234.1	$	190.0	$	0.4	$	(4.0	)	$	186.4

Investments Classified by Contractual Maturity Date

As of December 31, 2019, the contractual maturities of available-for-sale debt securities were as follows:    

Eversource (Millions of Dollars)	Amortized Cost		Fair Value
Less than one year (1)	$	59.2	$	59.3
One to five years	40.5		41.4
Six to ten years	33.6		34.8
Greater than ten years	95.1		98.6
Total Debt Securities	$	228.4	$	234.1

⁽¹⁾

Amounts in the Less than one year category include securities in the CYAPC and YAEC spent nuclear fuel trusts, which are restricted and are classified in long-term Marketable Securities on the balance sheets.

Marketable Securities Recorded at Fair Value

The following table presents the marketable securities recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:

Eversource (Millions of Dollars)	As of December 31,
	2019		2018
Level 1:
Mutual Funds and Equities	$	228.5	$	244.0
Money Market Funds	46.0		25.9
Total Level 1	$	274.5	$	269.9
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury)	$	96.8	$	79.6
Corporate Debt Securities	44.0		39.5
Asset-Backed Debt Securities	12.9		14.0
Municipal Bonds	26.7		19.2
Other Fixed Income Securities	7.7		8.2
Total Level 2	$	188.1	$	160.5
Total Marketable Securities	$	462.6	$	430.4

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SEGMENT INFORMATION - Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($) segment
Segment Reporting Information [Line Items]
Amount of natural gas transmission purchased | $	$ 62.5
CL&P
Segment Reporting Information [Line Items]
Number of reportable segments	1
NSTAR Electric
Segment Reporting Information [Line Items]
Number of reportable segments	1
PSNH
Segment Reporting Information [Line Items]
Number of reportable segments	1

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LONG-TERM DEBT - Schedule of Long-term Debt Maturities (Details) $ in Millions	Dec. 31, 2019 USD ($)
Debt Instrument [Line Items]
2020	$ 296.1
2021	1,033.6
2022	1,188.9
2023	1,665.2
2024	1,049.8
Thereafter	8,447.8
Total	13,681.4
CL&P
Debt Instrument [Line Items]
2020	0.0
2021	0.0
2022	0.0
2023	400.0
2024	139.8
Thereafter	2,975.5
Total	3,515.3
NSTAR Electric
Debt Instrument [Line Items]
2020	95.0
2021	250.0
2022	400.0
2023	80.0
2024	0.0
Thereafter	2,540.0
Total	3,365.0
PSNH
Debt Instrument [Line Items]
2020	0.0
2021	282.0
2022	0.0
2023	325.0
2024	0.0
Thereafter	350.0
Total	$ 957.0

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Fuel, Materials, Supplies and Inventory (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Public Utilities, Inventory [Line Items]
Total	$ 235.5	$ 238.0
Fuel
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	26.7	33.1
Materials and Supplies
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	132.9	126.1
RECs
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	75.9	78.8
CL&P
Public Utilities, Inventory [Line Items]
Total	50.7	44.5
CL&P | Fuel
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	0.0	0.0
CL&P | Materials and Supplies
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	50.7	44.5
CL&P | RECs
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	0.0	0.0
NSTAR Electric
Public Utilities, Inventory [Line Items]
Total	124.1	114.2
NSTAR Electric | Fuel
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	0.0	0.0
NSTAR Electric | Materials and Supplies
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	54.7	48.6
NSTAR Electric | RECs
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	69.4	65.6
PSNH
Public Utilities, Inventory [Line Items]
Total	25.0	37.5
PSNH | Fuel
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	0.0	0.0
PSNH | Materials and Supplies
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	18.5	24.3
PSNH | RECs
Public Utilities, Inventory [Line Items]
Other inventory, capitalized costs, gross	$ 6.5	$ 13.2

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of Other Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Summary of Accounting Policies [Line Items]
Excise and sales taxes	$ 163.1	$ 161.9	$ 157.4
Tax remittance to state for energy efficiency funds	21.4	46.8
CL&P
Summary of Accounting Policies [Line Items]
Excise and sales taxes	$ 141.1	$ 141.4	$ 137.5

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EMPLOYEE BENEFITS - Schedule of Pension Benefit Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Pension Plan
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation as of Beginning of Year	$ (5,520.0)	$ (5,936.5)
Service Cost	(67.7)	(84.8)	$ (71.3)
Interest Cost	(219.0)	(196.4)	(188.0)
Actuarial Gain/(Loss)	(815.3)	414.9
Benefits Paid	273.0	261.8
Benefits Paid - Lump Sum	20.0	14.2
Benefits Paid - SERP	7.3	6.8
Employee Transfers	0.0	0.0
Benefit Obligation as of End of Year	(6,321.7)	(5,520.0)	(5,936.5)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of Beginning of Year	4,573.9	4,739.5
Employer Contributions	112.5	185.6
Actual Return on Pension Plan Assets	575.2	(75.2)
Benefits Paid - Pension	(273.0)	(261.8)
Benefits Paid - Lump Sum	(20.0)	(14.2)
Employee Transfers	0.0	0.0
Fair Value of Pension Plan Assets as of End of Year	4,968.6	4,573.9	4,739.5
Funded Status as of December 31st	(1,353.1)	(946.1)
Other Postretirement Benefits Plan
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation as of Beginning of Year	(841.5)	(948.6)
Service Cost	(7.8)	(10.0)	(9.5)
Interest Cost	(32.7)	(30.7)	(27.1)
Actuarial Gain/(Loss)	(67.0)	102.5
Benefits Paid	50.0	45.3
Employee Transfers	0.0	0.0
Benefit Obligation as of End of Year	(899.0)	(841.5)	(948.6)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of Beginning of Year	849.6	922.2
Employer Contributions	9.3	9.3
Actual Return on Pension Plan Assets	127.0	(36.6)
Benefits Paid - Pension	(50.0)	(45.3)
Employee Transfers	0.0	0.0
Fair Value of Pension Plan Assets as of End of Year	935.9	849.6	922.2
Funded Status as of December 31st	36.9	8.1
CL&P | Pension Plan
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation as of Beginning of Year	(1,160.4)	(1,275.2)
Service Cost	(18.0)	(21.4)	(18.5)
Interest Cost	(45.7)	(41.8)	(41.6)
Actuarial Gain/(Loss)	(176.6)	106.1
Benefits Paid	60.2	59.6
Benefits Paid - Lump Sum	0.0	0.0
Benefits Paid - SERP	0.3	0.3
Employee Transfers	8.9	12.0
Benefit Obligation as of End of Year	(1,331.3)	(1,160.4)	(1,275.2)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of Beginning of Year	918.4	963.0
Employer Contributions	24.0	41.2
Actual Return on Pension Plan Assets	112.9	(14.2)
Benefits Paid - Pension	(60.2)	(59.6)
Benefits Paid - Lump Sum	0.0	0.0
Employee Transfers	(8.9)	(12.0)
Fair Value of Pension Plan Assets as of End of Year	986.2	918.4	963.0
Funded Status as of December 31st	(345.1)	(242.0)
CL&P | Other Postretirement Benefits Plan
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation as of Beginning of Year	(161.7)	(178.4)
Service Cost	(1.4)	(1.9)	(1.9)
Interest Cost	(6.3)	(5.8)	(5.3)
Actuarial Gain/(Loss)	(13.4)	14.4
Benefits Paid	10.8	10.1
Employee Transfers	(0.7)	(0.1)
Benefit Obligation as of End of Year	(172.7)	(161.7)	(178.4)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of Beginning of Year	120.6	135.9
Employer Contributions	0.0	0.0
Actual Return on Pension Plan Assets	17.1	(5.2)
Benefits Paid - Pension	(10.8)	(10.1)
Employee Transfers	(0.6)	0.0
Fair Value of Pension Plan Assets as of End of Year	126.3	120.6	135.9
Funded Status as of December 31st	(46.4)	(41.1)
NSTAR Electric | Pension Plan
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation as of Beginning of Year	(1,236.5)	(1,351.0)
Service Cost	(14.6)	(17.4)	(15.5)
Interest Cost	(49.0)	(43.5)	(42.7)
Actuarial Gain/(Loss)	(181.0)	98.6
Benefits Paid	67.1	66.9
Benefits Paid - Lump Sum	12.9	7.1
Benefits Paid - SERP	0.1	0.3
Employee Transfers	3.7	2.5
Benefit Obligation as of End of Year	(1,397.3)	(1,236.5)	(1,351.0)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of Beginning of Year	1,222.1	1,260.8
Employer Contributions	0.4	56.5
Actual Return on Pension Plan Assets	150.0	(18.7)
Benefits Paid - Pension	(67.1)	(66.9)
Benefits Paid - Lump Sum	(12.9)	(7.1)
Employee Transfers	(3.7)	(2.5)
Fair Value of Pension Plan Assets as of End of Year	1,288.8	1,222.1	1,260.8
Funded Status as of December 31st	(108.5)	(14.4)
NSTAR Electric | Other Postretirement Benefits Plan
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation as of Beginning of Year	(246.3)	(278.6)
Service Cost	(1.7)	(2.0)	(1.7)
Interest Cost	(9.5)	(8.7)	(8.7)
Actuarial Gain/(Loss)	(15.2)	28.4
Benefits Paid	15.4	14.5
Employee Transfers	(1.0)	0.1
Benefit Obligation as of End of Year	(258.3)	(246.3)	(278.6)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of Beginning of Year	379.1	405.5
Employer Contributions	6.0	5.2
Actual Return on Pension Plan Assets	57.0	(17.4)
Benefits Paid - Pension	(15.4)	(14.5)
Employee Transfers	(2.3)	0.3
Fair Value of Pension Plan Assets as of End of Year	424.4	379.1	405.5
Funded Status as of December 31st	166.1	132.8
PSNH | Pension Plan
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation as of Beginning of Year	(610.7)	(642.2)
Service Cost	(7.1)	(11.2)	(9.7)
Interest Cost	(24.0)	(22.0)	(21.2)
Actuarial Gain/(Loss)	(84.5)	39.2
Benefits Paid	30.3	26.2
Benefits Paid - Lump Sum	0.0	0.0
Benefits Paid - SERP	0.4	0.2
Employee Transfers	3.0	(0.9)
Benefit Obligation as of End of Year	(692.6)	(610.7)	(642.2)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of Beginning of Year	506.6	539.5
Employer Contributions	15.4	0.0
Actual Return on Pension Plan Assets	62.9	(7.6)
Benefits Paid - Pension	(30.3)	(26.2)
Benefits Paid - Lump Sum	0.0	0.0
Employee Transfers	(3.0)	0.9
Fair Value of Pension Plan Assets as of End of Year	551.6	506.6	539.5
Funded Status as of December 31st	(141.0)	(104.1)
PSNH | Other Postretirement Benefits Plan
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Benefit Obligation as of Beginning of Year	(91.9)	(101.1)
Service Cost	(0.7)	(1.1)	(1.3)
Interest Cost	(3.4)	(3.4)	(3.0)
Actuarial Gain/(Loss)	(3.1)	8.6
Benefits Paid	5.6	4.9
Employee Transfers	0.5	0.2
Benefit Obligation as of End of Year	(93.0)	(91.9)	(101.1)
Change in Pension Plan Assets:
Fair Value of Pension Plan Assets as of Beginning of Year	71.2	79.0
Employer Contributions	0.0	0.0
Actual Return on Pension Plan Assets	10.0	(2.9)
Benefits Paid - Pension	(5.6)	(4.9)
Employee Transfers	0.4	0.0
Fair Value of Pension Plan Assets as of End of Year	76.0	71.2	$ 79.0
Funded Status as of December 31st	$ (17.0)	$ (20.7)

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ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) - Schedule of Changes in AOCI By Component (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	$ 11,486,817	$ 11,086,242
OCI Before Reclassifications	(12,100)	(200)
Amounts Reclassified from AOCI	7,000	6,600
Net OCI	(5,100)	6,400
Ending balance	12,629,994	11,486,817
Total
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(60,000)	(66,403)
Ending balance	(65,059)	(60,000)
Qualified Cash Flow Hedging Instruments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(4,400)	(6,200)
OCI Before Reclassifications	0	0
Amounts Reclassified from AOCI	1,400	1,800
Net OCI	1,400	1,800
Ending balance	(3,000)	(4,400)
Unrealized Gains/(Losses) on Marketable Securities
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(500)	0
OCI Before Reclassifications	1,200	(500)
Amounts Reclassified from AOCI	0	0
Net OCI	1,200	(500)
Ending balance	700	(500)
Defined Benefit Plans
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	(55,100)	(60,200)
OCI Before Reclassifications	(13,300)	300
Amounts Reclassified from AOCI	5,600	4,800
Net OCI	(7,700)	5,100
Ending balance	$ (62,800)	$ (55,100)

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LEASES (Tables)

12 Months Ended

Dec. 31, 2019

Leases [Abstract]

Components of Lease Cost

The components of lease cost, prior to amounts capitalized, are as follows:

	For the Year Ended December 31, 2019
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
Financing Lease Cost:
Amortization of Right-of-use-Assets	$	1.7	$	0.7	$	0.2	$	0.1
Interest on Lease Liabilities	1.2		0.6		0.6		—
Total Finance Lease Cost	2.9		1.3		0.8		0.1
Operating Lease Cost	11.7		0.5		3.4		0.1
Variable Lease Cost	60.5		13.3		—		47.2
Total Lease Cost	$	75.1	$	15.1	$	4.2	$	47.4

Schedule of Rent Expense

Operating lease rental payments charged to expense in 2018 and 2017 (which exclude CL&P's and PSNH's energy purchase contracts) were as follows:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2018	$	10.8	$	10.9	$	11.8	$	2.5
2017	10.5		11.7		11.3		3.3

Supplemental Balance Sheet Information Related to Leases

Supplemental balance sheet information related to leases is as follows:

		As of December 31, 2019
(Millions of Dollars)	Balance Sheet Classification	Eversource		CL&P		NSTAR Electric		PSNH
Operating Leases:
Operating Lease Right-of-use-Assets, Net	Other Long-Term Assets	$	49.9	$	0.7	$	24.2	$	0.4
Operating Lease Liabilities
Operating Lease Liabilities - Current Portion	Other Current Liabilities	$	8.6	$	0.5	$	0.7	$	0.1
Operating Lease Liabilities - Long-Term	Other Long-Term Liabilities	41.3		0.2		23.5		0.3
Total Operating Lease Liabilities		$	49.9	$	0.7	$	24.2	$	0.4
Finance Leases:
Finance Lease Right-of-use-Assets, Net	Property, Plant and Equipment, Net	$	8.2	$	1.9	$	3.3	$	0.9
Finance Lease Liabilities
Finance Lease Liabilities - Current Portion	Other Current Liabilities	$	2.4	$	1.6	$	—	$	0.1
Finance Lease Liabilities - Long-Term	Other Long-Term Liabilities	8.1		1.4		4.4		0.8
Total Finance Lease Liabilities		$	10.5	$	3.0	$	4.4	$	0.9

Other Information Related to Leases

Other information related to leases is as follows (in millions of dollars, unless otherwise noted):

	Eversource		CL&P		NSTAR Electric		PSNH
As of December 31, 2019
Weighted-Average Remaining Lease Term (Years):
Operating Leases	12		2		20		9
Finance Leases	12		2		22		9
Weighted-Average Discount Rate (Percentage):
Operating Leases	3.9	%	2.5	%	4.1	%	3.7	%
Finance Leases	4.0	%	10.5	%	2.9	%	3.5	%

	Eversource		CL&P		NSTAR Electric		PSNH
For the Year Ended December 31, 2019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$	11.4	$	0.4	$	1.6	$	0.1
Operating Cash Flows from Finance Leases	1.2		0.6		0.6		—
Financing Cash Flows from Finance Leases	2.6		1.4		—		0.1
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	2.9		1.0		0.1		0.2
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	2.0		—		—		—

Future Minimum Lease Payments under Long-Term Leases

Future minimum lease payments, excluding variable costs, under long-term leases, as of December 31, 2019 are as follows:

	Operating Leases								Finance Leases
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Year Ending December 31,
2020	$	10.2	$	0.5	$	1.8	$	0.1	$	3.4	$	2.0	$	0.6	$	0.1
2021	9.0		0.2		1.6		0.1		2.9		1.5		0.6		0.1
2022	7.4		—		1.6		0.1		1.5		—		0.6		0.1
2023	4.9		—		1.6		—		0.8		—		0.6		0.1
2024	2.8		—		1.7		—		0.8		—		0.7		0.1
Thereafter	28.9		0.1		28.7		0.2		13.1		—		12.6		0.5
Future lease payments	63.2		0.8		37.0		0.5		22.5		3.5		15.7		1.0
Less amount representing interest	13.3		0.1		12.8		0.1		12.0		0.5		11.3		0.1
Present value of future minimum lease payments	$	49.9	$	0.7	$	24.2	$	0.4	$	10.5	$	3.0	$	4.4	$	0.9

Future Minimum Lease Payments under Long-Term Leases

Future minimum lease payments, excluding variable costs, under long-term leases, as of December 31, 2019 are as follows:

	Operating Leases								Finance Leases
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Year Ending December 31,
2020	$	10.2	$	0.5	$	1.8	$	0.1	$	3.4	$	2.0	$	0.6	$	0.1
2021	9.0		0.2		1.6		0.1		2.9		1.5		0.6		0.1
2022	7.4		—		1.6		0.1		1.5		—		0.6		0.1
2023	4.9		—		1.6		—		0.8		—		0.6		0.1
2024	2.8		—		1.7		—		0.8		—		0.7		0.1
Thereafter	28.9		0.1		28.7		0.2		13.1		—		12.6		0.5
Future lease payments	63.2		0.8		37.0		0.5		22.5		3.5		15.7		1.0
Less amount representing interest	13.3		0.1		12.8		0.1		12.0		0.5		11.3		0.1
Present value of future minimum lease payments	$	49.9	$	0.7	$	24.2	$	0.4	$	10.5	$	3.0	$	4.4	$	0.9

Future Minimum Rental Payments under Operating Leases

At December 31, 2018, future minimum rental payments, excluding executory costs, such as property taxes, state use taxes, insurance, and maintenance were as follows:

Operating Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	11.5	$	1.5	$	7.2	$	0.5
2020	9.8		1.4		6.0		0.4
2021	8.7		1.2		5.3		0.4
2022	7.2		1.1		4.4		0.4
2023	4.7		0.5		3.1		0.2
Thereafter	32.7		0.2		29.5		0.3
Future minimum lease payments	$	74.6	$	5.9	$	55.5	$	2.2

Future Minimum Rental Payments under Capital Leases

Capital Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	3.4	$	2.0	$	0.5	$	0.1
2020	3.4		2.0		0.5		0.1
2021	2.9		1.5		0.5		0.1
2022	1.5		—		0.6		0.1
2023	0.7		—		0.6		0.1
Thereafter	13.9		—		13.4		0.5
Future minimum lease payments	25.8		5.5		16.1		1.0
Less amount representing interest	13.8		1.0		12.4		0.1
Present value of future minimum lease payments	$	12.0	$	4.5	$	3.7	$	0.9

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PREFERRED STOCK NOT SUBJECT TO MANDATORY REDEMPTION (Tables)

12 Months Ended

Dec. 31, 2019

Equity [Abstract]

Schedule of Preferred Stock Not Subject to Mandatory Redemption

The following table sets forth the Eversource parent common shares and the shares of common stock of CL&P, NSTAR Electric and PSNH that were authorized and issued, as well as the respective per share par values:  

	Shares
	Par Value		Authorized as of December 31, 2019 and 2018	Issued as of December 31,
				2019	2018
Eversource	$	5	380,000,000	345,858,402	333,878,402
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

Details of preferred stock not subject to mandatory redemption are as follows (in millions, except in redemption price and shares):

		Redemption Price Per Share		Shares Outstanding as of December 31,		As of December 31,
Series				2019	2018	2019			2018
CL&P
$1.90	Series of 1947	$	52.50	163,912	163,912	$	8.2		$	8.2
$2.00	Series of 1947	$	54.00	336,088	336,088	16.8			16.8
$2.04	Series of 1949	$	52.00	100,000	100,000	5.0			5.0
$2.20	Series of 1949	$	52.50	200,000	200,000	10.0			10.0
3.90%	Series of 1949	$	50.50	160,000	160,000	8.0			8.0
$2.06	Series E of 1954	$	51.00	200,000	200,000	10.0			10.0
$2.09	Series F of 1955	$	51.00	100,000	100,000	5.0			5.0
4.50%	Series of 1956	$	50.75	104,000	104,000	5.2			5.2
4.96%	Series of 1958	$	50.50	100,000	100,000	5.0			5.0
4.50%	Series of 1963	$	50.50	160,000	160,000	8.0			8.0
5.28%	Series of 1967	$	51.43	200,000	200,000	10.0			10.0
$3.24	Series G of 1968	$	51.84	300,000	300,000	15.0			15.0
6.56%	Series of 1968	$	51.44	200,000	200,000	10.0			10.0
Total CL&P				2,324,000	2,324,000	$	116.2		$	116.2
NSTAR Electric
4.25%	Series of 1956	$	103.625	180,000	180,000	$	18.0		$	18.0
4.78%	Series of 1958	$	102.80	250,000	250,000	25.0			25.0
Total NSTAR Electric				430,000	430,000	$	43.0		$	43.0
Fair Value Adjustment due to Merger with NSTAR						(3.6		)	(3.6		)
Other
6.00%	Series of 1958	$	100.00	23	23	$	—		$	—
Total Eversource - Noncontrolling Interest - Preferred Stock of Subsidiaries						$	155.6		$	155.6

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COMMON SHARES - Common Shares Authorized and Issued (Details) - $ / shares	Dec. 31, 2019	Dec. 31, 2018
Class of Stock [Line Items]
Per share par value (in dollars per share)	$ 5	$ 5
Authorized (in shares)	380,000,000	380,000,000
Issued (in shares)	345,858,402	333,878,402
CL&P
Class of Stock [Line Items]
Per share par value (in dollars per share)	$ 10	$ 10
Authorized (in shares)	24,500,000	24,500,000
Issued (in shares)	6,035,205	6,035,205
NSTAR Electric
Class of Stock [Line Items]
Per share par value (in dollars per share)	$ 1	$ 1
Authorized (in shares)	100,000,000	100,000,000
Issued (in shares)	200	200
PSNH
Class of Stock [Line Items]
Per share par value (in dollars per share)	$ 1	$ 1
Authorized (in shares)	100,000,000	100,000,000
Issued (in shares)	301	301

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COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Equity [Abstract]
Net income attributable to noncontrolling interests	$ 7,500	$ 7,500	$ 7,500
Noncontrolling interest - preferred stock of subsidiaries	$ 155,570	$ 155,570

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ACQUISITION OF AQUARION AND GOODWILL (Tables)

12 Months Ended

Dec. 31, 2019

Business Combinations [Abstract]

Summary of Unaudited Pro Forma Financial Information

The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of Eversource.

(Pro forma amounts in millions, except share amounts)	For the Year Ended December 31, 2017
Operating Revenues	$	7,947.7
Net Income Attributable to Common Shareholders	1,019.1
Basic EPS	3.21
Diluted EPS	3.20

Summary of Goodwill by Reportable Segment

 The following table presents goodwill by reportable segment as of December 31, 2019 and 2018:

(Billions of Dollars)	Electric Distribution		Electric Transmission		Natural Gas Distribution		Water Distribution		Total
Goodwill	$	2.5	$	0.6	$	0.4	$	0.9	$	4.4

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SHORT-TERM DEBT - Narrative (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 18, 2019	Oct. 25, 2019	Dec. 08, 2017
Commercial Paper
Short-term Debt [Line Items]
Amount of commercial paper program	$ 346,300,000	$ 0
Line of Credit
Short-term Debt [Line Items]
Amount outstanding during period	0	0
Eversource | Commercial Paper
Short-term Debt [Line Items]
Amount of commercial paper program	1,450,000,000				$ 1,450,000,000
Eversource | Line of Credit
Short-term Debt [Line Items]
Amount of commercial paper program	$ 1,450,000,000
Debt instrument term	5 years
CL&P
Short-term Debt [Line Items]
Short-term borrowing limit approved by regulatory agency				$ 600,000,000
Notes payable to related parties	$ 63,800,000	0
NSTAR Electric
Short-term Debt [Line Items]
Short-term borrowing limit approved by regulatory agency			$ 655,000,000
Notes payable to related parties	30,300,000	0
NSTAR Electric | Commercial Paper
Short-term Debt [Line Items]
Amount of commercial paper program	650,000,000
NSTAR Electric | Line of Credit
Short-term Debt [Line Items]
Amount of commercial paper program	$ 650,000,000
Debt instrument term	5 years
PSNH
Short-term Debt [Line Items]
Short-term borrowing limit approved by regulatory agency	$ 354,000,000
Notes payable to related parties	$ 27,000,000	$ 57,000,000
PSNH | Short Term Debt Authorization Calculation
Short-term Debt [Line Items]
Interest rate stated percentage (up to) (as a percentage)	10.00%
Short-term debt borrowing calculation approved by regulatory agency	$ 60,000,000
Unsecured Debt | CL&P
Short-term Debt [Line Items]
Period of maturity restricting provisions of debt	10 years
Total capitalization (as a percentage)	10.00%
Capacity available under preferred stock provisions	$ 738,100,000

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DERIVATIVE INSTRUMENTS - Derivative Contracts at Fair Value (Details) MWh in Millions, MMBTU in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($) MMBTU MWh MW	Dec. 31, 2018 USD ($) MMBTU MW	Dec. 31, 2017 USD ($)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of costs or benefits borne under capacity-related contracts by United Illuminated Company (as a percentage)	20.00%
Amount of power to be purchased under capacity-related contract (up to) (in MW) | MW	676	787
Amount of natural gas to be purchased under futures contracts (in MMBtu) | MMBTU	9.6	12.5
Loss deferred as regulatory costs | $	$ 20.7	$ 25.0	$ 29.0
CL&P
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of costs or benefits borne under capacity-related contracts (as a percentage)	80.00%
Amount of energy to be purchased under renewable energy contract (in mwh) | MWh	0.1
Minimum | Level 3
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of exit price premiums related to derivative contracts	2.10%
Minimum | Level 3 | CL&P
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of exit price premiums related to derivative contracts	13.60%

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PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION - Investment in Utility Property, Plant and Equipment By Asset (Details) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Distribution - Electric	$ 15,880,000	$ 15,071,100
Distribution - Natural Gas	3,931,100	3,546,200
Transmission - Electric	10,958,400	10,153,900
Distribution - Water	1,726,500	1,639,800
Solar	200,200	164,100
Utility	32,696,200	30,575,100
Other Assets	1,025,600	778,600
Property, Plant and Equipment, Gross	33,721,800	31,353,700
Less: Accumulated Depreciation
Utility	(7,483,500)	(7,126,200)
Other	(387,400)	(336,700)
Total Accumulated Depreciation	(7,870,900)	(7,462,900)
Property, Plant and Equipment, Net	25,850,900	23,890,800
Construction Work in Progress	1,734,600	1,719,600
Total Property, Plant and Equipment, Net	27,585,470	25,610,428
CL&P
Property, Plant and Equipment [Line Items]
Distribution - Electric	6,485,500	6,176,400
Transmission - Electric	5,043,000	4,700,500
Solar	0	0
Property, Plant and Equipment, Gross	11,528,500	10,876,900
Less: Accumulated Depreciation
Total Accumulated Depreciation	(2,385,700)	(2,302,600)
Property, Plant and Equipment, Net	9,142,800	8,574,300
Construction Work in Progress	483,000	335,400
Total Property, Plant and Equipment, Net	9,625,765	8,909,701
NSTAR Electric
Property, Plant and Equipment [Line Items]
Distribution - Electric	7,163,700	6,756,400
Transmission - Electric	4,411,900	4,065,900
Solar	200,200	164,100
Property, Plant and Equipment, Gross	11,775,800	10,986,400
Less: Accumulated Depreciation
Total Accumulated Depreciation	(2,895,300)	(2,702,000)
Property, Plant and Equipment, Net	8,880,500	8,284,400
Construction Work in Progress	592,300	510,300
Total Property, Plant and Equipment, Net	9,472,770	8,794,700
PSNH
Property, Plant and Equipment [Line Items]
Distribution - Electric	2,271,100	2,178,600
Transmission - Electric	1,498,700	1,338,700
Solar	0	0
Property, Plant and Equipment, Gross	3,769,800	3,517,300
Less: Accumulated Depreciation
Total Accumulated Depreciation	(799,900)	(772,900)
Property, Plant and Equipment, Net	2,969,900	2,744,400
Construction Work in Progress	159,600	135,700
Total Property, Plant and Equipment, Net	$ 3,129,506	$ 2,880,073

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ASSET RETIREMENT OBLIGATIONS - Schedule of Reconciliation of Beginning and Ending Balance (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of Beginning of Year	$ 466.2	$ 419.1
Liabilities Incurred During the Year	30.3	11.3
Liabilities Settled During the Year	(21.3)	(36.6)
Accretion	27.1	25.5
Revisions in Estimated Cash Flows	(12.8)	46.9
Balance as of End of Year	489.5	466.2
CL&P
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of Beginning of Year	33.5	31.5
Liabilities Incurred During the Year	0.0	0.0
Liabilities Settled During the Year	(3.6)	0.0
Accretion	2.2	2.0
Revisions in Estimated Cash Flows	(0.1)	0.0
Balance as of End of Year	32.0	33.5
NSTAR Electric
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of Beginning of Year	72.4	44.6
Liabilities Incurred During the Year	30.3	11.3
Liabilities Settled During the Year	0.0	0.0
Accretion	3.5	2.2
Revisions in Estimated Cash Flows	(8.7)	14.3
Balance as of End of Year	97.5	72.4
PSNH
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance as of Beginning of Year	4.0	25.0
Liabilities Incurred During the Year	0.0	0.0
Liabilities Settled During the Year	0.0	(21.5)
Accretion	0.2	0.5
Revisions in Estimated Cash Flows	0.0	0.0
Balance as of End of Year	$ 4.2	$ 4.0

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MARKETABLE SECURITIES

12 Months Ended

Dec. 31, 2019

Investments, Debt and Equity Securities [Abstract]

MARKETABLE SECURITIES

MARKETABLE SECURITIES

Eversource holds marketable securities that are primarily used to fund certain non-qualified executive benefits.  The trusts that hold marketable securities are not subject to regulatory oversight by state or federal agencies.  CYAPC and YAEC maintain legally restricted trusts, each of which holds marketable securities, to fund the spent nuclear fuel removal obligations of their nuclear fuel storage facilities.

Equity Securities: Unrealized gains and losses on equity securities held in Eversource's non-qualified executive benefit trust are recorded in Other Income, Net on the statements of income. The fair value of these equity securities as of December 31, 2019 and 2018 was $45.7 million and $44.0 million, respectively.  For the years ended December 31, 2019 and 2018, there were unrealized gains of $9.8 million and unrealized losses of $4.3 million recorded in Other Income, Net related to these equity securities, respectively.

Eversource's equity securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of $182.8 million and $200.0 million as of December 31, 2019 and 2018, respectively.  Unrealized gains and losses for these spent nuclear fuel trusts are subject to regulatory accounting treatment and are recorded in Marketable Securities with the corresponding offset to Other Long-Term Liabilities on the balance sheets, with no impact on the statements of income.

Available-for-Sale Debt Securities:  The following is a summary of the available-for-sale debt securities, which are recorded at fair value and are included in current and long-term Marketable Securities on the balance sheets.

	As of December 31,
	2019									2018
Eversource (Millions of Dollars)	Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value
Debt Securities	$	228.4	$	5.8	$	(0.1	)	$	234.1	$	190.0	$	0.4	$	(4.0	)	$	186.4

Eversource's debt securities include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts in the amounts of $198.1 million and $143.9 million as of December 31, 2019 and 2018, respectively.  

Unrealized gains and losses on available-for-sale debt securities held in Eversource's non-qualified benefit trust are recorded in Accumulated Other Comprehensive Income. There have been no significant unrealized losses, other-than-temporary impairments, or credit losses for the years ended December 31, 2019 or 2018.  Factors considered in determining whether a credit loss exists include the duration and severity of the impairment, adverse conditions specifically affecting the issuer, and the payment history, ratings and rating changes of the security.  For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated.

As of December 31, 2019, the contractual maturities of available-for-sale debt securities were as follows:    

Eversource (Millions of Dollars)	Amortized Cost		Fair Value
Less than one year (1)	$	59.2	$	59.3
One to five years	40.5		41.4
Six to ten years	33.6		34.8
Greater than ten years	95.1		98.6
Total Debt Securities	$	228.4	$	234.1

⁽¹⁾ Amounts in the Less than one year category include securities in the CYAPC and YAEC spent nuclear fuel trusts, which are restricted and are classified in long-term Marketable Securities on the balance sheets.

Realized Gains and Losses:  Realized gains and losses are recorded in Other Income, Net for Eversource's benefit trust and are offset in Other Long-Term Liabilities for CYAPC and YAEC.  Eversource utilizes the specific identification basis method for the Eversource non-qualified benefit trust, and the average cost basis method for the CYAPC and YAEC spent nuclear fuel trusts to compute the realized gains and losses on the sale of marketable securities.

Fair Value Measurements:  The following table presents the marketable securities recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:

Eversource (Millions of Dollars)	As of December 31,
	2019		2018
Level 1:
Mutual Funds and Equities	$	228.5	$	244.0
Money Market Funds	46.0		25.9
Total Level 1	$	274.5	$	269.9
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury)	$	96.8	$	79.6
Corporate Debt Securities	44.0		39.5
Asset-Backed Debt Securities	12.9		14.0
Municipal Bonds	26.7		19.2
Other Fixed Income Securities	7.7		8.2
Total Level 2	$	188.1	$	160.5
Total Marketable Securities	$	462.6	$	430.4

U.S. government issued debt securities are valued using market approaches that incorporate transactions for the same or similar bonds and adjustments for yields and maturity dates.  Corporate debt securities are valued using a market approach, utilizing recent trades of the same or similar instruments and also incorporating yield curves, credit spreads and specific bond terms and conditions.  Asset-backed debt securities include collateralized mortgage obligations, commercial mortgage backed securities, and securities collateralized by auto loans, credit card loans or receivables.  Asset-backed debt securities are valued using recent trades of similar instruments, prepayment assumptions, yield curves, issuance and maturity dates, and tranche information.  Municipal bonds are valued using a market approach that incorporates reported trades and benchmark yields.  Other fixed income securities are valued using pricing models, quoted prices of securities with similar characteristics, and discounted cash flows.

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EMPLOYEE BENEFITS - Summary of Changes in Plan Assets and Benefit Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Pension Plan
Net Regulatory Assets [Abstract]
Actuarial Losses/(Gains) Arising During the Year	$ 591.6	$ 48.6
Actuarial Losses Reclassified as Net Periodic Benefit Expense	(137.8)	(140.1)
Unamortized Securitized Stranded Costs	0.0	(36.7)
Prior Service Cost Arising During the Year	0.0	0.0
Prior Service (Cost)/Credit Reclassified as Net Periodic Benefit (Expense)/Income	(0.7)	(3.9)
Prior Service Cost Securitized as Stranded Costs	0.0	(0.1)
Actuarial Loss	2,261.4	1,807.6
Prior Service Cost	5.6	6.3
Expected Actuarial Loss Expense	190.3
Expected Prior Service Cost Expense	0.9
OCI
Actuarial Losses/(Gains) Arising During the Year	15.4	0.7
Actuarial Losses Reclassified as Net Periodic Benefit Expense	(5.4)	(5.6)
Actuarial Losses Securitized as Stranded Costs	0.0	0.0
Prior Service Cost Arising During the Year	0.0	0.0
Prior Service (Cost)/Credit Reclassified as Net Periodic Benefit (Expense)/Income	(0.2)	(0.4)
Prior Service Costs Securitized as Stranded Costs		0.0
Actuarial Loss	90.8	80.8
Prior Service Cost	0.9	1.1
Expected Actuarial Loss	7.2
Expected Prior Service Cost	0.2
Other Postretirement Benefits Plan
Net Regulatory Assets [Abstract]
Actuarial Losses/(Gains) Arising During the Year	4.6	6.4
Actuarial Losses Reclassified as Net Periodic Benefit Expense	(8.0)	(9.9)
Unamortized Securitized Stranded Costs	0.0	(0.8)
Prior Service Cost Arising During the Year	0.0	1.3
Prior Service (Cost)/Credit Reclassified as Net Periodic Benefit (Expense)/Income	25.1	23.6
Prior Service Cost Securitized as Stranded Costs	0.0	(1.3)
Actuarial Loss	203.9	207.3
Prior Service Cost	(172.5)	(197.6)
Expected Actuarial Loss Expense	8.3
Expected Prior Service Cost Expense	(21.4)
OCI
Actuarial Losses/(Gains) Arising During the Year	2.3	(1.2)
Actuarial Losses Reclassified as Net Periodic Benefit Expense	(0.3)	(0.4)
Actuarial Losses Securitized as Stranded Costs	0.0	0.0
Prior Service Cost Arising During the Year	0.0	0.0
Prior Service (Cost)/Credit Reclassified as Net Periodic Benefit (Expense)/Income	(1.6)	0.0
Prior Service Costs Securitized as Stranded Costs		0.0
Actuarial Loss	7.0	5.0
Prior Service Cost	1.0	$ 2.6
Expected Actuarial Loss	0.2
Expected Prior Service Cost	$ 0.2

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EMPLOYEE BENEFITS - Defined Contribution Plan Narrative (Details)	12 Months Ended
	Dec. 31, 2019
Defined Contribution Plan, 401K
Defined Contribution Plan Disclosure [Line Items]
Employer matching contribution (as a percentage)	100.00%
Percentage of employees' pay (up to)	3.00%
Defined Contribution Plan, Alternate Contribution 401K
Defined Contribution Plan Disclosure [Line Items]
Employer matching contribution (as a percentage)	50.00%
Percentage of employees' pay (up to)	8.00%

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LONG-TERM DEBT

12 Months Ended

Dec. 31, 2019

Debt Disclosure [Abstract]

LONG-TERM DEBT

LONG-TERM DEBT

Details of long-term debt outstanding are as follows:

CL&P (Millions of Dollars)	As of December 31,
	2019			2018
First Mortgage Bonds:
7.875% 1994 Series D due 2024	$	139.8		$	139.8
5.750% 2004 Series B due 2034	130.0			130.0
5.625% 2005 Series B due 2035	100.0			100.0
6.350% 2006 Series A due 2036	250.0			250.0
5.750% 2007 Series B due 2037	150.0			150.0
6.375% 2007 Series D due 2037	100.0			100.0
5.500% 2009 Series A due 2019	—			250.0
2.500% 2013 Series A due 2023	400.0			400.0
4.300% 2014 Series A due 2044	475.0			475.0
4.150% 2015 Series A due 2045	350.0			350.0
3.200% 2017 Series A due 2027	500.0			300.0
4.000% 2018 Series A due 2048	800.0			500.0
Total First Mortgage Bonds	3,394.8			3,144.8
Pollution Control Revenue Bonds:
4.375% Fixed Rate Tax Exempt due 2028	120.5			120.5
Less Amounts due Within One Year	—			(250.0		)
Unamortized Premiums and Discounts, Net	27.8			10.2
Unamortized Debt Issuance Costs	(25.0		)	(21.5		)
CL&P Long-Term Debt	$	3,518.1		$	3,004.0

NSTAR Electric (Millions of Dollars)	As of December 31,
	2019			2018
Debentures:
5.750% due 2036	$	200.0		$	200.0
5.500% due 2040	300.0			300.0
2.375% due 2022	400.0			400.0
4.400% due 2044	300.0			300.0
3.250% due 2025	250.0			250.0
2.700% due 2026	250.0			250.0
3.200% due 2027	700.0			700.0
3.250% due 2029	400.0			—
Total Debentures	2,800.0			2,400.0
Notes:
5.900% Senior Notes Series B due 2034	50.0			50.0
6.700% Senior Notes Series D due 2037	40.0			40.0
5.100% Senior Notes Series E due 2020	95.0			95.0
3.500% Senior Notes Series F due 2021	250.0			250.0
3.880% Senior Notes Series G due 2023	80.0			80.0
2.750% Senior Notes Series H due 2026	50.0			50.0
Total Notes	565.0			565.0
Less Amounts due Within One Year	(95.0		)	—
Unamortized Premiums and Discounts, Net	(4.1		)	(2.5		)
Unamortized Debt Issuance Costs	(18.8		)	(17.7		)
NSTAR Electric Long-Term Debt	$	3,247.1		$	2,944.8

PSNH (Millions of Dollars)	As of December 31,
	2019			2018
First Mortgage Bonds:
5.600% Series M due 2035	$	50.0		$	50.0
4.500% Series P due 2019	—			150.0
4.050% Series Q due 2021	122.0			122.0
3.200% Series R due 2021	160.0			160.0
3.500% Series S due 2023	325.0			325.0
3.600% Series T due 2049	300.0			—
Total First Mortgage Bonds	957.0			807.0
Less Amounts due Within One Year	—			(150.0		)
Unamortized Premiums and Discounts, Net	(0.7		)	—
Unamortized Debt Issuance Costs	(4.7		)	(1.8		)
PSNH Long-Term Debt	$	951.6		$	655.2

OTHER (Millions of Dollars)	As of December 31,
	2019			2018
Yankee Gas - First Mortgage Bonds: 2.230% - 8.480% due 2020 - 2049	$	620.0		$	470.0
NSTAR Gas - First Mortgage Bonds: 3.740% - 9.950% due 2020 - 2049	460.0			385.0
Aquarion - Senior Note 4.000% due 2024	360.0			360.0
Aquarion - Unsecured Notes 0% - 6.430% due 2021 - 2049	335.3			289.5
Aquarion - Secured Debt 4.100% - 9.640% due 2021 - 2035	68.8			70.7
Eversource Parent - Debentures 4.500% due 2019	—			350.0
Eversource Parent - Senior Notes 2.500% - 4.250% due 2021 - 2029	4,000.0			4,000.0
Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)	11.6			39.5
Fair Value Adjustment (1)	109.1			144.7
Less Fair Value Adjustment - Current Portion (1)	(31.3		)	(36.2		)
Less Amounts due in One Year	(201.1		)	(401.1		)
Commercial Paper Classified as Long-Term Debt (See Note 8, Short-Term Debt)	346.3			—
Unamortized Premiums and Discounts, Net	(4.1		)	(4.2		)
Unamortized Debt Issuance Costs	(20.6		)	(23.2		)
Total Other Long-Term Debt	$	6,054.0		$	5,644.7
Total Eversource Long-Term Debt	$	13,770.8		$	12,248.7

⁽¹⁾ The fair value adjustment amount is the purchase price adjustments, net of amortization, required to record long-term debt at fair value on the dates of the 2012 merger with NSTAR and the 2017 acquisition of Aquarion.

Long-Term Debt Issuances and Repayments: The following table summarizes long-term debt issuances and repayments:

(Millions of Dollars)	Issue Date	Issuance/(Repayment)			Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P:
4.00% 2018 Series A First Mortgage Bonds (1)	April 2019	$	300.0		April 2048	Paid short-term borrowings that were used to pay long-term debt that matured on February 1, 2019 and fund capital expenditures and working capital
3.20% 2017 Series A First Mortgage Bonds (2)	September 2019	200.0			March 2027	Paid short-term borrowings and fund capital expenditures and working capital
5.50% 2009 Series A First Mortgage Bonds	February 2009	(250.0		)	February 2019	Paid at maturity on February 1, 2019
NSTAR Electric:
3.25% 2019 Debentures	May 2019	400.0			May 2029	Paid short-term borrowings that were used to fund investments in eligible green expenditures
PSNH:
3.60% 2019 Series T First Mortgage Bonds	June 2019	300.0			July 2049	Paid long-term debt that matured in December 2019, paid short-term borrowings and fund capital expenditures and working capital
4.50% 2009 Series P First Mortgage Bonds	December 2009	(150.0		)	December 2019	Paid at maturity on December 1, 2019
Other:
Eversource Parent 4.50% Debentures	November 2009	(350.0		)	November 2019	Paid at maturity on November 15, 2019
Eversource Parent 3.45% Series P Senior Notes	January 2020	350.0			January 2050	Paid short-term borrowings
NSTAR Gas 3.74% Series Q First Mortgage Bonds	July 2019	75.0			August 2049	Paid short-term borrowings and fund capital expenditures and working capital
Yankee Gas 2.23% Series P First Mortgage Bonds	September 2019	100.0			October 2024	Paid short-term borrowings and for general corporate purposes
Yankee Gas 3.30% Series Q First Mortgage Bonds	September 2019	100.0			October 2049	Paid short-term borrowings and for general corporate purposes
Yankee Gas 5.26% Series H First Mortgage Bonds	November 2004	(50.0		)	November 2019	Paid at maturity on November 1, 2019
Aquarion 3.54% Senior Notes	December 2019	45.0			December 2049	Paid short-term borrowings

⁽¹⁾ These bonds are part of the same series issued by CL&P in March 2018. The aggregate outstanding principal amount of these bonds is now $800 million.

⁽²⁾ These bonds are part of the same series issued by CL&P in March 2017. The aggregate outstanding principal amount of these bonds is now $500 million.

Long-Term Debt Issuance Authorizations: On February 27, 2019, the DPU approved NSTAR Electric's request for authorization to issue up to $800 million in long-term debt through December 31, 2020. On April 26, 2019, the NHPUC approved PSNH's request for authorization to issue up to $300 million in long-term debt through December 31, 2019. On August 14, 2019, PURA approved CL&P's request for authorization to issue up to $675 million in long-term debt through December 31, 2022. On December 11, 2019, PURA approved Aquarion Water Company of Connecticut's request for authorization to issue up to $45 million of long-term debt. On January 27, 2020, the DPU approved NSTAR Gas' request for authorization to issue up to $270 million in long-term debt through December 31, 2021.

Long-Term Debt Provisions:  The utility plant of CL&P, PSNH, Yankee Gas, NSTAR Gas and a portion of Aquarion is subject to the lien of each company's respective first mortgage bond indenture.  The Eversource parent, NSTAR Electric and a portion of Aquarion debt is unsecured.  Additionally, the long-term debt agreements provide that Eversource and certain of its subsidiaries must comply with certain covenants as are customarily included in such agreements, including equity requirements for NSTAR Electric, NSTAR Gas and Aquarion.  Under the equity requirements, NSTAR Electric's and Aquarion's senior notes must maintain a certain consolidated indebtedness to capitalization ratio as of the end of any fiscal quarter and NSTAR Gas' outstanding long-term debt must not exceed equity.

CL&P's obligation to repay the Pollution Control Revenue Bonds (PCRBs) is secured by first mortgage bonds.  The first mortgage bonds contain similar terms and provisions as the applicable series of PCRBs.  If CL&P fails to meet its obligations under the first mortgage bonds, then the holder of the first mortgage bonds (the issuer of the PCRBs) would have rights under the first mortgage bonds.  CL&P's tax-exempt PCRBs will be subject to redemption at par on or after September 1, 2021.  

Certain secured and unsecured long-term debt securities are callable at redemption price or are subject to make-whole provisions.

Eversource, NSTAR Electric, Yankee Gas and Aquarion have certain long-term debt agreements that contain cross-default provisions.  No other debt issuances contain cross-default provisions as of December 31, 2019.

CYAPC's Pre-1983 Spent Nuclear Fuel Obligation:  Under the Nuclear Waste Policy Act of 1982, the DOE is responsible for the selection and development of repositories for, and the disposal of, spent nuclear fuel and high-level radioactive waste. CYAPC is obligated to pay the DOE for the costs to dispose of spent nuclear fuel and high-level radioactive waste generated prior to April 7, 1983 (pre-1983 Spent Nuclear Fuel) and recorded an accrual for the full liability thereof to the DOE. This liability accrues interest costs at the 3-month Treasury bill yield rate. For nuclear fuel used to generate electricity prior to April 7, 1983, payment may be made any time prior to the first delivery of spent fuel to the DOE. Fees for disposal of nuclear fuel burned on or after April 7, 1983 were billed to member companies and paid to the DOE.

As of December 31, 2019 and 2018, as a result of consolidating CYAPC, Eversource has consolidated $11.6 million and $39.5 million, respectively, in pre-1983 spent nuclear fuel obligations to the DOE. In December 2019 and 2018, CYAPC paid $29 million and $145 million, respectively, to the DOE to partially settle this obligation. The obligation includes accumulated interest costs of $8.6 million and $29.0 million as of December 31, 2019 and 2018, respectively.  CYAPC maintains a trust to fund amounts due to the DOE for the disposal of pre-1983 spent nuclear fuel.  For further information, see Note 5, "Marketable Securities," to the financial statements.

Long-Term Debt Maturities:  Long-term debt maturities on debt outstanding for the years 2020 through 2024 and thereafter are shown below. These amounts exclude PSNH rate reduction bonds, CYAPC pre-1983 spent nuclear fuel obligation, net unamortized premiums, discounts and debt issuance costs, and other fair value adjustments as of December 31, 2019:

(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2020	$	296.1	$	—	$	95.0	$	—
2021	1,033.6		—		250.0		282.0
2022	1,188.9		—		400.0		—
2023	1,665.2		400.0		80.0		325.0
2024	1,049.8		139.8		—		—
Thereafter	8,447.8		2,975.5		2,540.0		350.0
Total	$	13,681.4	$	3,515.3	$	3,365.0	$	957.0

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COMMITMENTS AND CONTINGENCIES - Eversource and NSTAR Electric Boston Harbor Civil Action (Details) $ in Millions		12 Months Ended
	Jul. 15, 2016 kV	Dec. 31, 2019 USD ($) kV	Dec. 31, 2018 USD ($)	Dec. 31, 2017 USD ($)
Site Contingency [Line Items]
Amount of capacity required for installation of distribution cable (in kV) | kV	115	115
Asset retirement obligations		$ 489.5	$ 466.2	$ 419.1
NSTAR Electric
Site Contingency [Line Items]
Base rate credit for new cable			17.5
Asset retirement obligations		97.5	$ 72.4	$ 44.6
Long-Term Derivative Liabilities
Site Contingency [Line Items]
Asset retirement obligations		32.0
Long-Term Derivative Liabilities | NSTAR Electric
Site Contingency [Line Items]
Asset retirement obligations		$ 32.0

XML

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION (Tables)

12 Months Ended

Dec. 31, 2019

Property, Plant and Equipment [Abstract]

Schedule of Utility Property, Plant and Equipment

The following tables summarize property, plant and equipment by asset category:

Eversource	As of December 31,
(Millions of Dollars)	2019			2018
Distribution - Electric	$	15,880.0		$	15,071.1
Distribution - Natural Gas	3,931.1			3,546.2
Transmission - Electric	10,958.4			10,153.9
Distribution - Water	1,726.5			1,639.8
Solar	200.2			164.1
Utility	32,696.2			30,575.1
Other (1)	1,025.6			778.6
Property, Plant and Equipment, Gross	33,721.8			31,353.7
Less:  Accumulated Depreciation
Utility	(7,483.5		)	(7,126.2		)
Other	(387.4		)	(336.7		)
Total Accumulated Depreciation	(7,870.9		)	(7,462.9		)
Property, Plant and Equipment, Net	25,850.9			23,890.8
Construction Work in Progress	1,734.6			1,719.6
Total Property, Plant and Equipment, Net	$	27,585.5		$	25,610.4

	As of December 31,
	2019									2018
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Distribution - Electric	$	6,485.5		$	7,163.7		$	2,271.1		$	6,176.4		$	6,756.4		$	2,178.6
Transmission - Electric	5,043.0			4,411.9			1,498.7			4,700.5			4,065.9			1,338.7
Solar	—			200.2			—			—			164.1			—
Property, Plant and Equipment, Gross	11,528.5			11,775.8			3,769.8			10,876.9			10,986.4			3,517.3
Less:  Accumulated Depreciation	(2,385.7		)	(2,895.3		)	(799.9		)	(2,302.6		)	(2,702.0		)	(772.9		)
Property, Plant and Equipment, Net	9,142.8			8,880.5			2,969.9			8,574.3			8,284.4			2,744.4
Construction Work in Progress	483.0			592.3			159.6			335.4			510.3			135.7
Total Property, Plant and Equipment, Net	$	9,625.8		$	9,472.8		$	3,129.5		$	8,909.7		$	8,794.7		$	2,880.1

⁽¹⁾ 

These assets are primarily comprised of computer software, hardware and equipment at Eversource Service and buildings at The Rocky River Realty Company.

The depreciation rates for the various classes of utility property, plant and equipment aggregate to composite rates as follows:

(Percent)	2019		2018		2017
Eversource	3.0	%	2.9	%	3.0	%
CL&P	2.8	%	2.8	%	2.8	%
NSTAR Electric	2.8	%	2.8	%	2.9	%
PSNH	2.8	%	2.8	%	3.1	%

The following table summarizes average remaining useful lives of depreciable assets:

	As of December 31, 2019
(Years)	Eversource	CL&P	NSTAR Electric	PSNH
Distribution - Electric	34.3	35.3	33.7	33.2
Distribution - Natural Gas	43.2	—	—	—
Transmission - Electric	40.4	36.8	44.9	42.1
Distribution - Water	33.5	—	—	—
Solar	24.2	—	24.2	—
Other (1)	11.2	—	—	—

⁽¹⁾ 

The estimated useful life of computer software, hardware and equipment primarily ranges from 5 to 15 years and of buildings is 40 years.

XML

REGULATORY ACCOUNTING

12 Months Ended

Dec. 31, 2019

Regulated Operations [Abstract]

REGULATORY ACCOUNTING

REGULATORY ACCOUNTING

Eversource's utility companies are subject to rate regulation that is based on cost recovery and meets the criteria for application of accounting guidance for rate-regulated operations, which considers the effect of regulation on the timing of the recognition of certain revenues and expenses. The regulated companies' financial statements reflect the effects of the rate-making process.  The rates charged to the customers of Eversource's regulated companies are designed to collect each company's costs to provide service, plus a return on investment.  

The application of accounting guidance for rate-regulated enterprises results in recording regulatory assets and liabilities.  Regulatory assets represent the deferral of incurred costs that are probable of future recovery in customer rates.  Regulatory assets are amortized as the incurred costs are recovered through customer rates.  Regulatory liabilities represent either revenues received from customers to fund expected costs that have not yet been incurred or probable future refunds to customers.

Management believes it is probable that each of the regulated companies will recover its respective investments in long-lived assets, including regulatory assets.  If management were to determine that it could no longer apply the accounting guidance applicable to rate-regulated enterprises to any of the regulated companies' operations, or if management could not conclude it is probable that costs would be recovered from customers in future rates, the costs would be charged to net income in the period in which the determination is made.

Regulatory Assets:  The components of regulatory assets were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Benefit Costs	$	2,382.9	$	539.0	$	629.8	$	218.2	$	1,914.8	$	424.7	$	544.4	$	169.6
Income Taxes, Net	725.8		458.8		108.0		12.8		728.6		454.4		105.9		8.3
Securitized Stranded Costs	565.3		—		—		565.3		608.4		—		—		608.4
Storm Restoration Costs, Net	540.6		274.6		200.6		65.4		576.0		302.6		212.9		60.5
Regulatory Tracker Mechanisms	411.5		78.3		207.1		65.8		316.0		33.2		169.1		67.3
Derivative Liabilities	334.5		329.2		—		—		356.5		356.5		—		—
Goodwill-related	331.5		—		284.6		—		348.4		—		299.1		—
Asset Retirement Obligations	97.2		30.8		50.3		3.6		89.2		32.3		42.2		3.3
Other Regulatory Assets	125.4		25.2		55.2		14.7		208.0		27.0		64.6		12.1
Total Regulatory Assets	5,514.7		1,735.9		1,535.6		945.8		5,145.9		1,630.7		1,438.2		929.5
Less:  Current Portion	651.1		178.6		285.6		84.1		514.8		125.2		241.7		67.2
Total Long-Term Regulatory Assets	$	4,863.6	$	1,557.3	$	1,250.0	$	861.7	$	4,631.1	$	1,505.5	$	1,196.5	$	862.3

Benefit Costs:  Eversource's Pension, SERP and PBOP Plans are accounted for in accordance with accounting guidance on defined benefit pension and other PBOP plans.  The liability (or asset) recorded by the regulated companies to recognize the funded status of their retiree benefit plans is offset by a regulatory asset (or offset by a regulatory liability in the case of a benefit plan asset) in lieu of a charge to Accumulated Other Comprehensive Income/(Loss), reflecting ultimate recovery from customers through rates.  The regulatory asset (or regulatory liability) is amortized as the actuarial gains and losses and prior service cost are amortized to net periodic benefit cost for the pension and PBOP plans.  All amounts are remeasured annually.  Regulatory accounting is also applied to the portions of Eversource's service company costs that support the regulated companies, as these amounts are also recoverable.  As these regulatory assets or regulatory liabilities do not represent a cash outlay for the regulated companies, no carrying charge is recovered from customers. See Note 11A, "Employee Benefits - Pensions and Postretirement Benefits Other Than Pension," for further information on regulatory benefit plan amounts recognized and amortized during the year.

CL&P, NSTAR Electric and PSNH recover benefit costs related to their distribution and transmission operations from customers in rates as allowed by their applicable regulatory commissions.  NSTAR Electric recovers qualified pension and PBOP expenses related to its distribution operations through a rate reconciling mechanism that fully tracks the change in net pension and PBOP expenses each year.  

Income Taxes, Net:  The tax effect of temporary book-tax differences (differences between the periods in which transactions affect income in the financial statements and the periods in which they affect the determination of taxable income, including those differences relating to uncertain tax positions) is accounted for in accordance with the rate-making treatment of the applicable regulatory commissions and accounting guidance for income taxes.  Differences in income taxes between the accounting guidance and the rate-making treatment of the applicable regulatory commissions are recorded as regulatory assets.  As these assets are offset by deferred income tax liabilities, no carrying charge is collected.  The amortization period of these assets varies depending on the nature and/or remaining life of the underlying assets and liabilities.  For further information regarding income taxes, see Note 12, "Income Taxes," to the financial statements.  

Securitized Stranded Costs: In 2018, a subsidiary of PSNH issued $635.7 million of securitized RRBs to finance PSNH's unrecovered remaining costs associated with the divestiture of its generation assets. Securitized regulatory assets, which are not earning an equity return, are being recovered over the amortization period of the associated RRBs. The PSNH RRBs are expected to be repaid by February 1, 2033. For further information, see Note 10, "Rate Reduction Bonds and Variable Interest Entities."

Storm Restoration Costs, Net: The storm restoration cost deferrals relate to costs incurred for storm events at CL&P, NSTAR Electric and PSNH that each company expects to recover from customers.  A storm must meet certain criteria to qualify for deferral and recovery with the criteria specific to each state jurisdiction and utility company. Once a storm qualifies for recovery, all qualifying expenses incurred during storm restoration efforts are deferred and recovered from customers. Costs for storms that do not meet the specific criteria are expensed as incurred. In addition to storm restoration costs, CL&P and PSNH are each allowed to recover pre-staging storm costs. Management believes storm restoration costs deferred were prudently incurred and meet the criteria for specific cost recovery in Connecticut, Massachusetts and New Hampshire, and that recovery from customers is probable through the applicable regulatory recovery processes. Each electric utility company either recovers a carrying charge on its deferred storm restoration cost regulatory asset balance or the regulatory asset balance is included in rate base.

In 2019, several significant storms caused extensive damage to our electric distribution systems and customer outages. These storms resulted in deferred storm restoration costs of approximately $126 million ($62 million for CL&P, $48 million for NSTAR Electric, and $16 million for PSNH), which were reflected in Storm Restoration Costs, Net in the table above as of December 31, 2019.

Storm Filings: On November 16, 2018, CL&P filed for recovery of $153 million of storm costs incurred from October 2017 through May 2018, with recovery over six years.  Through the course of the proceeding, CL&P updated its request to $145.5 million to reflect final invoicing and capitalization amounts. On April 17, 2019, PURA authorized recovery of $141.0 million as part of storm cost recovery and the remainder to be recorded to plant or other balance sheet accounts. CL&P began recovery of the $141.0 million in distribution rates effective May 1, 2019.

On March 26, 2019, the NHPUC approved the recovery of $38.1 million, plus carrying charges, of storm costs incurred from December 2013 through April 2016 and the transfer of funding from PSNH’s major storm reserve to recover those costs. The costs of these storms (excluding the equity return component of the carrying charges) were deferred as regulatory assets, and the funding reserve collected from customers was accrued as a regulatory liability. As a result of the duration of time between incurring storm costs in December 2013 through April 2016 and final approval from the NHPUC in 2019, PSNH recognized $5.2 million (pre-tax) for the equity return component of the carrying charges within Other Income, Net on the statement of income in 2019, which has been collected from customers. Also included in the March 26, 2019 NHPUC approval is a prospective requirement for PSNH to annually net its storm funding reserve collected from customers against deferred storm costs.

In addition, on June 27, 2019, the NHPUC approved a temporary rate settlement that allowed PSNH to recover approximately $68.5 million in unrecovered storm costs over a five-year period beginning August 1, 2019, with debt carrying charges.

Regulatory Tracker Mechanisms:  The regulated companies' approved rates are designed to recover costs incurred to provide service to customers. The regulated companies recover certain of their costs on a fully-reconciling basis through regulatory commission-approved tracking mechanisms. The differences between the costs incurred (or the rate recovery allowed) and the actual revenues are recorded as regulatory assets (for undercollections) or as regulatory liabilities (for overcollections) to be included in future customer rates each year.  Carrying charges are recovered in rates on all material regulatory tracker mechanisms.

CL&P, NSTAR Electric and PSNH each recover, on a fully reconciling basis, the costs associated with the procurement of energy, transmission related costs from FERC-approved transmission tariffs, energy efficiency programs, low income assistance programs, certain uncollectible accounts receivable for hardship customers, and restructuring and stranded costs as a result of deregulation (including securitized RRB charges), and additionally for the Massachusetts utilities, pension and PBOP benefits and net metering for distributed generation. Energy procurement costs at NSTAR Electric include the costs related to its solar power facilities.

CL&P, NSTAR Electric, Yankee Gas and NSTAR Gas each have a regulatory commission approved revenue decoupling mechanism. Distribution revenues are decoupled from customer sales volumes, where applicable, which breaks the relationship between sales volumes and revenues.  Each company reconciles its annual base distribution rate recovery amount to the pre-established levels of baseline distribution delivery service revenues. Any difference between the allowed level of distribution revenue and the actual amount realized during a 12-month period is adjusted through rates in the following period. 

Derivative Liabilities:  Regulatory assets are recorded as an offset to derivative liabilities and relate to the fair value of contracts used to purchase energy and energy-related products that will be recovered from customers in future rates.  These assets are excluded from rate base and are being recovered as the actual settlements occur over the duration of the contracts.  See Note 4, "Derivative Instruments," to the financial statements for further information on these contracts.

Goodwill-related:  The goodwill regulatory asset originated from a 1999 transaction, and the DPU allowed its recovery in NSTAR Electric and NSTAR Gas rates.  This regulatory asset is currently being amortized and recovered from customers in rates without a carrying charge over a 40-year period, and as of December 31, 2019, there were 20 years of amortization remaining.

Asset Retirement Obligations: The costs associated with the depreciation of the regulated companies' ARO assets and accretion of the ARO liabilities are recorded as regulatory assets in accordance with regulatory accounting guidance. The regulated companies' ARO assets, regulatory assets and liabilities offset and are excluded from rate base. These costs are being recovered over the life of the underlying property, plant and equipment.

Other Regulatory Assets:  Other Regulatory Assets primarily include contractual obligations associated with the spent nuclear fuel storage costs of the CYAPC, YAEC and MYAPC decommissioned nuclear power facilities, environmental remediation costs, losses associated with the reacquisition or redemption of long-term debt, certain uncollectible accounts receivable for hardship customers, certain merger-related costs allowed for recovery, water tank painting costs, and various other items.

Regulatory Costs in Long-Term Assets:  Eversource's regulated companies had $146.0 million (including $51.8 million for CL&P, $55.7 million for NSTAR Electric and $18.0 million for PSNH) and $122.9 million (including $42.1 million for CL&P, $49.3 million for NSTAR Electric and $12.2 million for PSNH) of additional regulatory costs as of December 31, 2019 and 2018, respectively, that were included in long-term assets on the balance sheets.  These amounts represent incurred costs for which recovery has not yet been specifically approved by the applicable regulatory agency.  However, based on regulatory policies or past precedent on similar costs, management believes it is probable that these costs will ultimately be approved and recovered from customers in rates.  

Equity Return on Regulatory Assets:  For rate-making purposes, the regulated companies recover the carrying costs related to their regulatory assets.  For certain regulatory assets, the carrying cost recovered includes an equity return component.  This equity return, which is not recorded on the balance sheets, totaled $0.5 million and $0.7 million for CL&P as of December 31, 2019 and 2018, respectively, and $6.5 million and $12.0 million for PSNH as of December 31, 2019 and 2018, respectively. These carrying costs will be recovered from customers in future rates.  

Regulatory Liabilities:  The components of regulatory liabilities were as follows:

	As of December 31,
	2019								2018
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
EDIT due to Tax Cuts and Jobs Act	$	2,844.6	$	1,022.8	$	1,071.2	$	392.8	$	2,883.0	$	1,031.0	$	1,103.7	$	396.4
Cost of Removal	559.8		64.6		330.6		16.3		521.0		39.9		307.1		22.1
Benefit Costs	84.5		—		72.2		—		91.2		—		76.9		—
Regulatory Tracker Mechanisms	325.1		94.8		165.6		57.0		309.0		89.5		163.7		48.3
AFUDC - Transmission	73.2		46.0		27.2		—		70.7		47.4		23.3		—
Revenue Subject to Refund due to Tax Cuts   and Jobs Act	14.6		—		—		6.0		24.6		—		—		12.6
Other Regulatory Liabilities	117.4		19.6		59.0		7.1		80.2		24.0		29.2		4.2
Total Regulatory Liabilities	4,019.2		1,247.8		1,725.8		479.2		3,979.7		1,231.8		1,703.9		483.6
Less:  Current Portion	361.2		82.8		209.2		65.8		370.2		109.6		190.6		55.5
Total Long-Term Regulatory Liabilities	$	3,658.0	$	1,165.0	$	1,516.6	$	413.4	$	3,609.5	$	1,122.2	$	1,513.3	$	428.1

EDIT due to Tax Cuts and Jobs Act: Pursuant to the "Tax Cuts and Jobs Act" (the Act), which became law on December 22, 2017, Eversource had remeasured its existing deferred federal income tax balances to reflect the decrease in the U.S. federal corporate income tax rate from 35 percent to 21 percent. The remeasurement resulted in provisional regulated excess accumulated deferred income tax (excess ADIT or EDIT) liabilities that will benefit our customers in future periods and were recognized as regulatory liabilities on the balance sheet. EDIT liabilities related to property, plant, and equipment are subject to IRS normalization rules and will be returned to customers using the same timing as the remaining useful lives of the underlying assets that gave rise to the ADIT liabilities.

Eversource's regulated companies are in the process of, or will be, refunding the EDIT liabilities to customers based on orders issued by applicable state regulatory commissions. For CL&P (effective May 1, 2019) and Yankee Gas (effective November 15, 2018), the refund of EDIT liabilities was incorporated into base distribution rates. For NSTAR Electric (effective January 1, 2019) and NSTAR Gas (effective February 1, 2019), the refund of EDIT liabilities occurred in rates through a new reconciling factor. For PSNH, EDIT refunds will be addressed as part of the permanent distribution rate case filing. The EDIT balance related to PSNH's divested generation assets was included as a component of the securitization of the stranded generation assets and began to be refunded to customers, effective August 1, 2018. For our transmission companies, on November 21, 2019, the FERC issued its final rule requiring public utilities with transmission formula rates to make adjustments to ADIT and EDIT. Eversource expects to submit a filing demonstrating its compliance with the final rule in the second half of 2020.

Cost of Removal:  Eversource's regulated companies currently recover amounts in rates for future costs of removal of plant assets over the lives of the assets.  The estimated cost to remove utility assets from service is recognized as a component of depreciation expense, and the cumulative amount collected from customers but not yet expended is recognized as a regulatory liability.  

AFUDC - Transmission:  Regulatory liabilities were recorded by CL&P and NSTAR Electric for AFUDC accrued on certain reliability-related transmission projects to reflect local rate base recovery.  These regulatory liabilities will be amortized over the depreciable life of the related transmission assets.

Revenue Subject to Refund due to Tax Cuts and Jobs Act: Eversource established a regulatory liability with a corresponding reduction to revenue, to reflect the difference between the 35 percent federal corporate income tax rate included in rates charged to customers and the 21 percent federal corporate income tax rate, effective January 1, 2018 as a result of the Tax Cuts and Jobs Act, until rates billed to customers reflected the lower federal tax rate. Effective May 1, 2018, CL&P adjusted distribution rates billed to customers to reflect the lower federal income tax rate prospectively and, as of December 31, 2018, fully refunded its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through April 30, 2018. Effective November 15, 2018, Yankee Gas adjusted distribution rates to reflect the lower federal income tax rate prospectively and to refund its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through November 14, 2018. Effective July 1, 2019, PSNH adjusted temporary distribution rates to reflect the lower federal income tax rate prospectively and to refund its regulatory liability associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 through June 30, 2019. For NSTAR Electric and NSTAR Gas, a December 2018 DPU order indicated that the DPU would not require a revision to base distribution rates for any potential refunds associated with the higher federal corporate income tax rate billed to customers in the period between January 1, 2018 to the effective dates of each company's rate changes (effective February 1, 2018 for NSTAR Electric and July 1, 2018 for NSTAR Gas).

Effective January 1, 2018, local transmission service rates were updated to reflect the lower U.S. federal corporate income tax rate that resulted from the act. On June 28, 2018, FERC granted a one-time tariff waiver of tariff provisions related to the federal corporate income tax rate so that effective June 1, 2018, the regional transmission service rates also reflected the reduced federal corporate income tax rate at 21 percent.

FERC ROE Complaints:  As of December 31, 2019, Eversource has a reserve established for the second ROE complaint in the pending FERC ROE complaint proceedings, which was recorded as a regulatory liability and is reflected within Regulatory Tracker Mechanisms in the table above.  The cumulative pre-tax reserve (excluding interest) as of December 31, 2019 totaled $39.1 million for Eversource (including $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH). See Note 13E, "Commitments and Contingencies – FERC ROE Complaints," for further information on developments in the pending ROE complaint proceedings.

XML

DOCUMENT AND ENTITY INFORMATION - USD ($)	12 Months Ended
	Dec. 31, 2019	Jan. 31, 2020	Jun. 30, 2019
Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2019
Document Transition Report	false
Entity Registrant Name	EVERSOURCE ENERGY
Entity Incorporation, State or Country Code	MA
Entity Address, Address Line One	300 Cadwell Drive
Entity Address, City or Town	Springfield
Entity Address, State or Province	MA
Entity Address, Postal Zip Code	01104
City Area Code	800
Local Phone Number	286-5000
Entity File Number	1-5324
Entity Tax Identification Number	04-2147929
Title of 12(b) Security	Common Shares, $5.00 par value per share
Trading Symbol	ES
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 24,486,439,602
Entity Common Stock, Shares Outstanding		329,952,663
Entity Central Index Key	0000072741
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Amendment Flag	false
The Connecticut Light and Power Company
Entity Information [Line Items]
Entity Registrant Name	THE CONNECTICUT LIGHT AND POWER COMPANY
Entity Incorporation, State or Country Code	CT
Entity Address, Address Line One	107 Selden Street
Entity Address, City or Town	Berlin
Entity Address, State or Province	CT
Entity Address, Postal Zip Code	06037-1616
City Area Code	800
Local Phone Number	286-5000
Entity File Number	0-00404
Entity Tax Identification Number	06-0303850
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		6,035,205
Entity Central Index Key	0000023426
Current Fiscal Year End Date	--12-31
NSTAR Electric Company
Entity Information [Line Items]
Entity Registrant Name	NSTAR ELECTRIC COMPANY
Entity Incorporation, State or Country Code	MA
Entity Address, Address Line One	800 Boylston Street
Entity Address, City or Town	Boston
Entity Address, State or Province	MA
Entity Address, Postal Zip Code	02199
City Area Code	800
Local Phone Number	286-5000
Entity File Number	1-02301
Entity Tax Identification Number	04-1278810
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		200
Entity Central Index Key	0000013372
Current Fiscal Year End Date	--12-31
Public Service Company of New Hampshire
Entity Information [Line Items]
Entity Registrant Name	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
Entity Incorporation, State or Country Code	NH
Entity Address, Address Line One	Energy Park
Entity Address, Address Line Two	780 North Commercial Street
Entity Address, City or Town	Manchester
Entity Address, State or Province	NH
Entity Address, Postal Zip Code	03101-1134
City Area Code	800
Local Phone Number	286-5000
Entity File Number	1-6392
Entity Tax Identification Number	02-0181050
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		301
Entity Central Index Key	0000315256
Current Fiscal Year End Date	--12-31

XML

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS AND RESERVES

12 Months Ended

Dec. 31, 2019

SEC Schedule, 12-09, Valuation and Qualifying Accounts [Abstract]

SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS AND RESERVES

SCHEDULE II

EVERSOURCE ENERGY AND SUBSIDIARIES

VALUATION AND QUALIFYING ACCOUNTS AND RESERVES

FOR THE YEARS ENDED DECEMBER 31, 2019, 2018 AND 2017

(Thousands of Dollars)

Column A		Column B		Column C				Column D		Column E
				Additions
				(1)		(2)
				Charged		Charged to
		Balance as		to Costs		Other		Deductions -		Balance
		of Beginning		and		Accounts -		Describe		as of
Description:		of Year		Expenses		Describe (a)		(b)		End of Year
Eversource:
Reserves Deducted from Assets -
Reserves for Uncollectible Accounts:
	2019	$	212,723	$	63,446	$	57,223	$	108,571	$	224,821
	2018	195,708		61,337		48,671		92,993		212,723
	2017	200,630		44,665		47,630		97,217		195,708
CL&P:
Reserves Deducted from Assets -
Reserves for Uncollectible Accounts:
	2019	$	88,034	$	15,947	$	38,935	$	45,568	$	97,348
	2018	78,872		15,831		29,524		36,193		88,034
	2017	86,391		5,312		25,533		38,364		78,872
NSTAR Electric:
Reserves Deducted from Assets -
Reserves for Uncollectible Accounts:
	2019	$	74,516	$	25,079	$	12,556	$	36,745	$	75,406
	2018	69,666		22,279		14,971		32,400		74,516
	2017	70,284		21,252		14,273		36,143		69,666
PSNH:
Reserves Deducted from Assets -
Reserves for Uncollectible Accounts:
	2019	$	11,065	$	6,726	$	872	$	8,166	$	10,497
	2018	10,481		6,383		953		6,752		11,065
	2017	9,941		6,917		464		6,841		10,481

(a) Amounts relate to uncollectible accounts receivables reserved for that are not charged to bad debt expense.  The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively.  The DPU allows NSTAR Electric and NSTAR Gas to recover in rates, amounts associated with certain uncollectible hardship accounts receivable. 

(b)

Amounts written off, net of recoveries.

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COMMITMENTS AND CONTINGENCIES - Spent Nuclear Fuel Obligations Narrative (Details) - USD ($) $ in Thousands				1 Months Ended		12 Months Ended
	Jun. 12, 2019	Feb. 21, 2019	May 22, 2017	Dec. 31, 2019	Jul. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Guarantor Obligations [Line Items]
Net of damages awarded	$ 500
Remaining damages sought	$ 1,000
Damages paid					$ 500
DOE settlement payment				$ 29,000		$ (29,000)	$ (145,000)	$ 0
Yankee Companies
Guarantor Obligations [Line Items]
Damages sought			$ 104,400
YAEC
Guarantor Obligations [Line Items]
Net of damages awarded				2,800
Total amount of damages awarded				5,400
MYAPC
Guarantor Obligations [Line Items]
Net of damages awarded				5,000
Total amount of damages awarded				$ 21,000
CYAPC, YAEC, And MYAPC
Guarantor Obligations [Line Items]
Net of damages awarded		$ 103,200
CYAPC
Guarantor Obligations [Line Items]
Net of damages awarded		40,700
YAEC
Guarantor Obligations [Line Items]
Net of damages awarded		28,100
MYAPC
Guarantor Obligations [Line Items]
Net of damages awarded		$ 34,400

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COMMITMENTS AND CONTINGENCIES - Environmental Matters Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019 USD ($) site	Dec. 31, 2018 USD ($) site	Dec. 31, 2017 USD ($)
Loss Contingencies [Line Items]
Number of sites | site	57	60
Reserve	$ 81.0	$ 64.7	$ 54.9
CL&P
Loss Contingencies [Line Items]
Number of sites | site	15	15
Reserve	$ 11.4	$ 5.4	4.7
NSTAR Electric
Loss Contingencies [Line Items]
Number of sites | site	15	16
Reserve	$ 8.0	$ 10.9	2.7
PSNH
Loss Contingencies [Line Items]
Number of sites | site	9	9
Reserve	$ 7.5	$ 5.4	$ 5.7
MGP Site accrual
Loss Contingencies [Line Items]
Reserve balances related to former MGP sites	$ 67.9	$ 50.1
Environmental Sites for Which a Range of Loss Exists
Loss Contingencies [Line Items]
Number of sites | site	6
Reserve	$ 35.9
Best estimate of potential remediation costs (up to)	$ 35.0
Environmental Sites for Which a Range of Loss Exists | CL&P
Loss Contingencies [Line Items]
Number of sites | site	1
Reserve	$ 0.4
Best estimate of potential remediation costs (up to)	$ 0.5
Environmental Site for Which a Range is Too Early to Determine
Loss Contingencies [Line Items]
Number of sites | site	15
Reserve	$ 7.4
Environmental Site for Which a Range is Too Early to Determine | CL&P
Loss Contingencies [Line Items]
Number of sites | site	7
Reserve	$ 2.3
Environmental Site for Which a Range is Too Early to Determine | NSTAR Electric
Loss Contingencies [Line Items]
Number of sites | site	4
Reserve	$ 1.9
Evironmental Sites with Best Estimate
Loss Contingencies [Line Items]
Number of sites | site	36
Reserve	$ 37.7
Evironmental Sites with Best Estimate | CL&P
Loss Contingencies [Line Items]
Reserve	$ 8.7
Environmental site quantity remaining | site	7
Evironmental Sites with Best Estimate | NSTAR Electric
Loss Contingencies [Line Items]
Reserve	$ 6.1
Environmental site quantity remaining | site	11
Evironmental Sites with Best Estimate | PSNH
Loss Contingencies [Line Items]
Reserve	$ 7.5
Environmental site quantity remaining | site	9

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CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY - USD ($) $ in Thousands	Total	Common Shares	Capital Surplus, Paid In	Retained Earnings	Accumulated Other Comprehensive Loss	Treasury Stock	The Connecticut Light and Power Company	The Connecticut Light and Power Company Common Shares	The Connecticut Light and Power Company Capital Surplus, Paid In	The Connecticut Light and Power Company Retained Earnings	The Connecticut Light and Power Company Accumulated Other Comprehensive Loss	NSTAR Electric Company	NSTAR Electric Company Common Shares	NSTAR Electric Company Capital Surplus, Paid In	NSTAR Electric Company Retained Earnings	NSTAR Electric Company Accumulated Other Comprehensive Loss	Public Service Company of New Hampshire	Public Service Company of New Hampshire Common Shares	Public Service Company of New Hampshire Capital Surplus, Paid In	Public Service Company of New Hampshire Retained Earnings	Public Service Company of New Hampshire Accumulated Other Comprehensive Loss
Beginning Balance (in shares) at Dec. 31, 2016		316,885,808						6,035,205					200					301
Beginning balance at Dec. 31, 2016	$ 10,711,734	$ 1,669,392	$ 6,250,224	$ 3,175,171	$ (65,282)	$ (317,771)	$ 3,470,387	$ 60,352	$ 2,110,714	$ 1,299,374	$ (53)	$ 3,342,843	$ 0	$ 1,500,642	$ 1,844,195	$ (1,994)	$ 1,387,357	$ 0	$ 843,134	$ 549,286	$ (5,063)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	995,515			995,515			376,726			376,726		374,726			374,726		135,996			135,996
Dividends on Common Stock	(602,083)			(602,083)			(254,800)			(254,800)		(272,000)			(272,000)		(173,900)			(173,900)
Dividends on Preferred Stock	(7,519)			(7,519)			(5,559)			(5,559)		(1,960)			(1,960)
Capital Stock Expenses, Net							51		51
Capital Contributions from Eversource Parent												2,300		2,300
Long-Term Incentive Plan Activity	(10,834)		(10,834)
Other Changes in Shareholders' Equity	550		550
Other Comprehensive Income (Loss)	(1,121)				(1,121)		322				322	171				171	1,141				1,141
Ending Balance (in shares) at Dec. 31, 2017		316,885,808						6,035,205					200					301
Ending balance at Dec. 31, 2017	11,086,242	$ 1,669,392	6,239,940	3,561,084	(66,403)	(317,771)	3,587,127	$ 60,352	2,110,765	1,415,741	269	3,446,080	$ 0	1,502,942	1,944,961	(1,823)	1,350,594	$ 0	843,134	511,382	(3,922)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	1,040,519			1,040,519			377,717			377,717		383,090			383,090		115,876			115,876
Dividends on Common Stock	(640,110)			(640,110)			(60,000)			(60,000)		(228,000)			(228,000)
Dividends on Preferred Stock	(7,519)			(7,519)			(5,559)			(5,559)		(1,960)			(1,960)
Return of Capital																	(530,000)		(530,000)
Capital Contributions from Eversource Parent	365,000						300,000		300,000			130,500		130,500					365,000
Long-Term Incentive Plan Activity	(543)		(543)
Other Changes in Shareholders' Equity	1,825		1,825
Other Comprehensive Income (Loss)	$ 6,403				6,403		32				32	445				445	1,071				1,071
Ending Balance (in shares) at Dec. 31, 2018	316,885,808	316,885,808						6,035,205					200					301
Ending balance at Dec. 31, 2018	$ 11,486,817	$ 1,669,392	6,241,222	3,953,974	(60,000)	(317,771)	4,199,317	$ 60,352	2,410,765	1,727,899	301	3,730,155	$ 0	1,633,442	2,098,091	(1,378)	1,302,541	$ 0	678,134	627,258	(2,851)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	916,572			916,572			410,852			410,852		431,956			431,956		134,048			134,048
Dividends on Common Stock	(685,979)			(685,979)			(341,800)			(341,800)		(181,800)			(181,800)		(271,000)			(271,000)
Dividends on Preferred Stock	$ (7,519)			(7,519)			(5,559)			(5,559)		(1,960)			(1,960)
Capital Contributions from Eversource Parent							125,000		125,000			180,000		180,000			225,000		225,000
Issuance of Common Shares (in shares)	11,980,000	11,980,000
Issuance of Common Shares	$ 868,550	$ 59,900	808,650
Long-Term Incentive Plan Activity	3,434		3,434
Issuance of Treasury Shares (in shares)		1,014,837
Issuance of Treasury Shares	69,474		50,758			18,716
Capital Stock Expense	(16,296)		(16,296)
Other Comprehensive Income (Loss)	$ (5,059)				(5,059)		15				15	1,533				1,533	1,144				1,144
Ending Balance (in shares) at Dec. 31, 2019	329,880,645	329,880,645						6,035,205					200					301
Ending balance at Dec. 31, 2019	$ 12,629,994	$ 1,729,292	$ 7,087,768	$ 4,177,048	$ (65,059)	$ (299,055)	$ 4,387,825	$ 60,352	$ 2,535,765	$ 1,791,392	$ 316	$ 4,159,884	$ 0	$ 1,813,442	$ 2,346,287	$ 155	$ 1,391,733	$ 0	$ 903,134	$ 490,306	$ (1,707)

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SEGMENT INFORMATION

12 Months Ended

Dec. 31, 2019

Segment Reporting [Abstract]

SEGMENT INFORMATION

SEGMENT INFORMATION

Eversource is organized into the Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reportable segments and Other based on a combination of factors, including the characteristics of each segments' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates.  These reportable segments represent substantially all of Eversource's total consolidated revenues.  Revenues from the sale of electricity, natural gas and water primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer.  The Electric Distribution reportable segment includes the results of PSNH's generation facilities prior to sales in January and August 2018, and NSTAR Electric's solar power facilities. On December 4, 2017, Eversource acquired Aquarion, and its water distribution business was deemed a reportable segment beginning in 2018. Eversource's reportable segments are determined based upon the level at which Eversource's chief operating decision maker assesses performance and makes decisions about the allocation of company resources.  

The remainder of Eversource's operations is presented as Other in the tables below and primarily consists of 1) the equity in earnings of Eversource parent from its subsidiaries and intercompany interest income, both of which are eliminated in consolidation, and interest expense related to the debt of Eversource parent, 2) the revenues and expenses of Eversource Service, most of which are eliminated in consolidation, 3) the operations of CYAPC and YAEC, 4) Eversource Water Ventures, Inc., parent company of Aquarion, 5) the results of other unregulated subsidiaries, which are not part of its core business, and 6) Eversource parent's equity ownership interests that are not consolidated, which primarily include the offshore wind business, a natural gas pipeline owned by Enbridge, Inc., and a renewable energy investment fund.

In the ordinary course of business, Yankee Gas and NSTAR Gas purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline project described above. These affiliate transaction costs total $62.5 million annually and are classified as Purchased Power, Fuel and Transmission on the Eversource statements of income.

Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has one reportable segment.  

Cash flows used for investments in plant included in the segment information below are cash capital expenditures that do not include amounts incurred but not paid, cost of removal, AFUDC related to equity funds, and the capitalized portions of pension and PBOP expense.

Eversource's segment information is as follows:

	For the Year Ended December 31, 2019
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues	$	6,976.5		$	1,062.2		$	1,389.0		$	214.6		$	1,028.5		$	(2,144.3	)	$	8,526.5
Depreciation and Amortization	(651.3		)	(68.3		)	(253.3		)	(46.9		)	(63.2		)	2.3			(1,080.7		)
Impairment of Northern Pass Transmission	—			—			(239.6		)	—			—			—			(239.6		)
Other Operating Expenses	(5,525.1		)	(830.8		)	(411.2		)	(101.0		)	(891.3		)	2,143.7			(5,615.7		)
Operating Income	800.1			163.1			484.9			66.7			74.0			1.7			1,590.5
Interest Expense	(206.4		)	(47.4		)	(125.7		)	(34.6		)	(170.3		)	51.2			(533.2		)
Interest Income	13.3			0.1			1.5			—			48.7			(50.8		)	12.8
Other Income, Net	46.8			1.6			29.2			0.4			1,041.5			(999.5		)	120.0
Income Tax (Expense)/Benefit	(135.9		)	(21.2		)	(130.5		)	2.4			11.7			—			(273.5		)
Net Income	517.9			96.2			259.4			34.9			1,005.6			(997.4		)	916.6
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income Attributable to Common Shareholders	$	513.3		$	96.2		$	256.5		$	34.9		$	1,005.6		$	(997.4	)	$	909.1
Total Assets (as of)	$	22,541.9		$	4,345.5		$	10,904.0		$	2,351.7		$	20,469.6		$	(19,488.8	)	$	41,123.9
Cash Flows Used for Investments in Plant	$	1,104.2		$	460.2		$	987.0		$	118.0		$	242.1		$	—		$	2,911.5

	For the Year Ended December 31, 2018
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues (1)	$	6,957.2		$	1,022.2		$	1,286.3		$	212.0		$	936.3		$	(1,965.8	)	$	8,448.2
Depreciation and Amortization	(671.8		)	(75.0		)	(231.8		)	(46.5		)	(49.1		)	2.2			(1,072.0		)
Other Operating Expenses (1)	(5,548.6		)	(787.6		)	(375.5		)	(99.8		)	(831.5		)	1,966.7			(5,676.3		)
Operating Income	736.8			159.6			679.0			65.7			55.7			3.1			1,699.9
Interest Expense	(202.8		)	(44.1		)	(120.6		)	(34.3		)	(129.3		)	32.3			(498.8		)
Interest Income	18.7			—			2.4			—			30.3			(33.3		)	18.1
Other Income/(Loss), Net	67.5			7.1			31.1			(0.4		)	1,185.3			(1,180.3		)	110.3
Income Tax (Expense)/Benefit	(160.2		)	(29.4		)	(161.8		)	(0.1		)	62.5			—			(289.0		)
Net Income	460.0			93.2			430.1			30.9			1,204.5			(1,178.2		)	1,040.5
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income Attributable to Common Shareholders	$	455.4		$	93.2		$	427.2		$	30.9		$	1,204.5		$	(1,178.2	)	$	1,033.0
Total Assets (as of)	$	21,389.1		$	3,904.9		$	10,285.0		$	2,253.0		$	17,874.2		$	(17,464.9	)	$	38,241.3
Cash Flows Used for Investments in Plant (2)	$	961.3		$	351.5		$	976.2		$	102.3		$	178.6		$	—		$	2,569.9

	For the Year Ended December 31, 2017
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues (1)	$	5,542.9		$	947.3		$	1,301.7		$	15.9		$	931.0		$	(986.8	)	$	7,752.0
Depreciation and Amortization	(542.6		)	(72.9		)	(209.4		)	(3.7		)	(37.4		)	2.2			(863.8		)
Other Operating Expenses (1)	(4,072.6		)	(716.4		)	(382.8		)	(8.3		)	(806.6		)	986.7			(5,000.0		)
Operating Income	927.7			158.0			709.5			3.9			87.0			2.1			1,888.2
Interest Expense	(186.3		)	(43.1		)	(115.1		)	(3.1		)	(90.0		)	15.8			(421.8		)
Interest Income	7.3			0.1			1.8			0.1			15.7			(16.7		)	8.3
Other Income, Net	41.6			3.8			27.3			—			1,113.0			(1,086.0		)	99.7
Income Tax Expense	(288.3		)	(44.2		)	(228.7		)	(2.1		)	(15.5		)	(0.1		)	(578.9		)
Net Income/(Loss)	502.0			74.6			394.8			(1.2		)	1,110.2			(1,084.9		)	995.5
Net Income Attributable to Noncontrolling Interests	(4.6		)	—			(2.9		)	—			—			—			(7.5		)
Net Income/(Loss) Attributable to Common Shareholders	$	497.4		$	74.6		$	391.9		$	(1.2	)	$	1,110.2		$	(1,084.9	)	$	988.0
Cash Flows Used for Investments in Plant	$	1,020.7		$	298.2		$	867.6		$	16.0		$	145.6		$	—		$	2,348.1

⁽¹⁾ Effective January 1, 2018, upon implementation of the new revenue accounting guidance, the electric distribution segment is presented gross and intercompany transmission billings are presented in the eliminations column, as Eversource believes that the electric distribution segment acts as a principal, rather than an agent, in its contracts with retail customers. Retail customers contract directly with the electric distribution utility and do not differentiate between distribution and transmission services. Therefore, the electric distribution segment revenues, which are derived from retail customer billings, are presented gross of the eliminations. Prior to 2018, the electric distribution segment presented intercompany electric transmission billings net, based on indicators of net presentation prior to the new revenue guidance.  See Note 23 "Revenues," to the financial statements regarding accounting for revenues.

⁽²⁾

See Note 1B, "Summary of Significant Accounting Policies - Basis of Presentation," for information regarding the correction of cash investments in plant reported in 2018.