Eversource Energy (ES, NYSE)
Industry: Utilities - Regulated Electric
Annual report, fiscal year 2019


## 2019
Annual
Report

## EVERSOURCE



Diluted Earnings Per Share \( ^{(1)} \) 



Dividends Per Share



(1) Diluted Earnings per Share (Non-GAAP) for 2019 was adjusted to exclude an after-tax impairment charge of $0.64 related to the Northern Pass Transmission Project. 2015 Diluted Earnings per Share was adjusted to exclude integration and merger-related costs of $0.05.

## Total Shareholder Return

(Assumes $100 invested on December 31, 2009 with all dividends reinvested)






## Selected Financial Data

(Thousands of dollars, except share information and statistical data)

<table><tr><td></td><td>2019</td><td>2018</td></tr><tr><td>Operating Revenues</td><td>$ 8,526,470</td><td>$ 8,448,201</td></tr><tr><td>Net Income Attributable to ES Common Shares</td><td>$ 909,053</td><td>$ 1,033,000</td></tr><tr><td>Diluted Earnings per Common Share (GAAP)</td><td>$ 2.81</td><td>$ 3.25</td></tr><tr><td>Diluted Earnings per Common Share (Non-GAAP) (1)</td><td>$ 3.45</td><td>$ 3.25</td></tr><tr><td>Diluted Common Shares Outstanding (Weighted Average)</td><td>$ 322,941,636</td><td>$ 317,993,934</td></tr><tr><td>Dividends per Common Share</td><td>$ 2.14</td><td>$ 2.02</td></tr><tr><td>Electric Customers (As of Year End)</td><td>3,223,951</td><td>3,202,992</td></tr><tr><td>Natural Gas Customers (As of Year End)</td><td>539,860</td><td>533,295</td></tr><tr><td>Water Customers (As of Year End)</td><td>228,523</td><td>227,632</td></tr><tr><td>Investments in Property, Plant and Equipment</td><td>$ 2,911,489</td><td>$ 2,569,936</td></tr><tr><td>Property, Plant and Equipment, Net (As of Year End)</td><td>$ 27,585,470</td><td>$ 25,610,428</td></tr><tr><td>Market Capitalization (As of Year End)</td><td>$ 28,062,946</td><td>$ 20,610,253</td></tr><tr><td>Share Price (As of Year End)</td><td>$ 85.07</td><td>$ 65.04</td></tr></table>

(1) Diluted Earnings per Common Share (Non-GAAP) for 2019 was adjusted to exclude an after-tax impairment charge of $0.64 per share related to the Northern Pass Transmission Project. See Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations," in the accompanying Form 10-K for a reconciliation to GAAP.

## Company Profile

Eversource Energy (NYSE:ES), a Fortune 500 and Standard & Poor's 500 energy company based in Connecticut, Massachusetts and New Hampshire, operates New England's largest energy delivery system. Eversource is committed to safety, reliability, environmental leadership and stewardship for its 4 million electricity, natural gas and water customers.

## Eversource
Service Territory

Electric Only

Natural Gas Only

Water Only

Combination



## Letter from Chairman Jim Judge

2019 was Eversource Energy’s best year in our history. We posted strong operational and financial performance and excellent returns for investors, while embracing and defining our growing role as a catalyst for clean energy.

We made significant progress on initiatives that support the clean energy vision that our customers, investors, regulators and legislators have identified as a priority. Our 50-50 partnership with Ørsted is now the nation’s leading offshore wind developer, with approved contracts for about 1,700 megawatts, including a contract signed in 2019 to provide 880 megawatts to New York electric customers for 25 years.

We are advancing innovative energy storage projects for our customers. Our utility-owned solar installations are in service and producing renewable energy for the region. And we are tripling the number of electric vehicle charging stations in Massachusetts through a $45 million investment in infrastructure.

We unveiled our plan to be carbon neutral by 2030, the only US energy utility with such an ambitious goal. It is consistent with our strategy of being the catalyst for clean energy development in New England and another way we can lead by example on climate action.

Our ability to shape our region’s energy future is based on a bedrock of strong financial performance. We had a total return for shareholders of 34.4 percent in 2019, compared with 25.8 percent for the EEI index and 31.5 percent for the S&P 500. This continues a trend of outperforming our peers on a short-, medium-, and long-term basis.

We reported recurring earnings per share of $3.45, an increase of 6.2 percent from 2018 excluding a one-time impairment charge of $0.64 per share related to our decision to cancel our Northern Pass Transmission project. While we felt Northern Pass offered clear economic and environmental benefits to customers, resistance to siting of the project in New Hampshire proved insurmountable. We continue to project long-term EPS growth of 5 percent to 7 percent, accompanied by similar dividend growth. In 2019, we raised the common dividend to $2.14 per share on an annualized basis from $2.02, and in February 2020, we announced a 6.1 percent increase to $2.27 per share.

We successfully completed our first issuance of “green bonds,” issuing $400 million to support low-carbon clean energy initiatives. Also, we successfully sold approximately $1.3 billion of new equity to support our projected $17 billion of investments from 2019 through



## Eversource's #1 honors



utility on the Forbes/JUST Capital Most Just Companies list, honoring our combination of corporate social responsibility and business success.



energy efficiency provider in the nation, according to ACEEE. We invest more than $500 million a year to help customers save energy and money.



developer of offshore wind in North America, with Ørsted. We’re a catalyst for clean energy, helping to shape our region’s energy future.



energy company on Newsweek’s list of Most Responsible Companies, recognizing our commitment to corporate social responsibility.



2024 in our core business, while also helping to finance our offshore wind partnership. The utility investments will enable our customers to continue to receive the safe and reliable electricity, natural gas and water service they expect.

Those core utility operations performed very well in 2019. We continue to deliver top-decile electric reliability, reducing the frequency and length of electric outages. We are consistently working to improve customer experience, with new offerings like a mobile app, expanded outage-related communications, and upgrades to the process to start, stop, or transfer service. Our safety record remained strong, with performance in the top tier of the industry. Aquarion, our water delivery company, continues to deliver very good service and solid financial performance, justifying our decision to enter the water business.

We remain the nation’s #1 provider of energy efficiency programs, investing more than $500 million in 2019 alone to help customers save about 1 billion kilowatt-hours and over 10 million therms per year and reduce their energy costs by nearly $200 million per year. We announced new energy efficiency partnerships with many organizations and communities that will benefit from our proven and innovative energy-saving solutions.

Our natural gas operations focused on safe, reliable service, including our ongoing program of gas line replacement. Our NSTAR Gas operations in Massachusetts filed for a rate review to recover $38 million in costs primarily associated with distribution system improvements and increases in labor and health care costs and property taxes. Our request also included innovative pilot projects that explore opportunities to develop geothermal energy, incorporate renewable and more responsibly produced natural gas into our supply, and establish a demand response program.

Our many community partners again benefited from the generous support of Eversource and its employees. Our signature community events were well-attended and successful, benefiting both charitable organizations and communities. We provided $18 million in donations and other support to community agencies, as well as more than 37,000 volunteer hours. Our United Way campaign again raised more than $1 million in employee donations, and with matching funds our total impact was $2.2 million.

Diversity & Inclusion remains a key focus, with our D&I Councils and Business Resource Groups working throughout the company to build and maintain a supportive culture where all employees feel welcome and engaged. We were chosen for the 2019 Bloomberg Gender-Equality Index, which distinguishes companies committed to transparency in gender reporting and advancing women’s equality.

## Our Total Return to Shareholders

<table><tr><td></td><td>2019</td><td>3-Year</td><td>5-Year</td><td>10-Year</td></tr><tr><td>Eversource</td><td>34.4%</td><td>68.7%</td><td>85.8%</td><td>356.7%</td></tr><tr><td>EEI 40-Company Index</td><td>25.8%</td><td>45.7%</td><td>64.4%</td><td>214.0%</td></tr><tr><td>S&amp;P 500</td><td>31.5%</td><td>53.2%</td><td>73.9%</td><td>256.7%</td></tr></table>







As an organization, we are focused on what's next for 2020 and beyond. We continue to advance our ambitious carbon neutral goal. In offshore wind, we'll be working through the permitting review process for existing project commitments and participating in additional requests for proposals as states work to fulfill and expand their offshore wind capacity demands. And, we will continue with our grid modernization efforts and the core capital investment that keeps our delivery systems so reliable.

The national awards and honors we received this year are a testament to our employees' hard work and our commitment to excellence. In addition to the Gender-Equality Index previously mentioned, we were recognized with the following honors:

• JUST Capital and Forbes magazine’s Most JUST Companies list – #1 utility company.

• Newsweek magazine’s Most Responsible Companies list – #1 Energy & Utilities company.

• American Council for an Energy-Efficient Economy – Massachusetts ranked first on the organization’s energy efficiency scorecard for the ninth straight year.

• We received the ENERGY STAR Partner of the Year Sustained Excellence Award in all three states for our energy efficiency programs.

• We achieved top-decile environmental, social, and governance (ESG) performance among utilities nationally, as assessed by the two leading sustainability rating firms.

• We were one of only 15 companies selected nationwide for the 2019 Secretary of Defense Employer Support Freedom Award, the military’s highest employer honor, which recognizes companies’ support for employees on military duty.

• We earned the Edison Electric Institute’s Emergency Recovery Award, recognizing our response to the July 2019 Cape Cod tornadoes.

In February 2020, we announced an agreement to acquire Columbia Gas' natural gas assets in Massachusetts for $1.1 billion in cash. Following state and federal regulatory reviews, we expect to close on the transaction by the end of the third quarter of 2020. We expect this transaction to be accretive in the first year after closing. It would also benefit customers and support the state's greenhouse gas reduction goals through accelerated pipe replacement and access to our best-in-class energy efficiency programs.

Eversource Energy is paving the way to a sustainable and prosperous future in the states we serve. We are proud to be a catalyst for clean energy, and I thank our 8,300 employees for their hard work and commitment to our customers and communities.



Chairman, President and Chief Executive Officer



# EVERSOURCE
ENERGY

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:

<table><tr><td>Title of each class</td><td>Trading Symbol(s)</td><td>Name of each exchange on which registered</td></tr><tr><td>Common Shares, $5.00 par value per share</td><td>ES</td><td>New York Stock Exchange</td></tr></table>

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:

<table><tr><td>$1.90</td><td>Series</td><td>of 1947</td></tr><tr><td>$2.00</td><td>Series</td><td>of 1947</td></tr><tr><td>$2.04</td><td>Series</td><td>of 1949</td></tr><tr><td>$2.20</td><td>Series</td><td>of 1949</td></tr><tr><td>3.90%</td><td>Series</td><td>of 1949</td></tr><tr><td>$2.06</td><td>Series E</td><td>of 1954</td></tr><tr><td>$2.09</td><td>Series F</td><td>of 1955</td></tr><tr><td>4.50%</td><td>Series</td><td>of 1956</td></tr><tr><td>4.96%</td><td>Series</td><td>of 1958</td></tr><tr><td>4.50%</td><td>Series</td><td>of 1963</td></tr><tr><td>5.28%</td><td>Series</td><td>of 1967</td></tr><tr><td>$3.24</td><td>Series G</td><td>of 1968</td></tr><tr><td>6.56%</td><td>Series</td><td>of 1968</td></tr></table>

NSTAR Electric Company

Preferred Stock, par value $100.00 per share, issuable in series, of which the following series are outstanding:

<table><tr><td>4.25%</td><td>Series</td><td>of 1956</td></tr><tr><td>4.78%</td><td>Series</td><td>of 1958</td></tr></table>

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.

<table><tr><td>Eversource Energy</td><td>Large accelerated filer</td><td>☑</td><td>Accelerated filer</td><td>☐</td><td>Non-accelerated filer</td><td>☐</td><td>Smaller reporting company</td><td>☐</td><td>Emerging growth company</td><td>☐</td></tr><tr><td>The Connecticut Light and Power Company</td><td>Large accelerated filer</td><td>☐</td><td>Accelerated filer</td><td>☐</td><td>Non-accelerated filer</td><td>☑</td><td>Smaller reporting company</td><td>☐</td><td>Emerging growth company</td><td>☐</td></tr><tr><td>NSTAR Electric Company</td><td>Large accelerated filer</td><td>☐</td><td>Accelerated filer</td><td>☐</td><td>Non-accelerated filer</td><td>☑</td><td>Smaller reporting company</td><td>☐</td><td>Emerging growth company</td><td>☐</td></tr><tr><td>Public Service Company of New Hampshire</td><td>Large accelerated filer</td><td>☐</td><td>Accelerated filer</td><td>☐</td><td>Non-accelerated filer</td><td>☑</td><td>Smaller reporting company</td><td>☐</td><td>Emerging growth company</td><td>☐</td></tr></table>

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):

<table><tr><td></td><td>Yes</td><td>No</td></tr><tr><td>Eversource Energy</td><td>☐</td><td>☑</td></tr><tr><td>The Connecticut Light and Power Company</td><td>☐</td><td>☑</td></tr><tr><td>NSTAR Electric Company</td><td>☐</td><td>☑</td></tr><tr><td>Public Service Company of New Hampshire</td><td>☐</td><td>☑</td></tr></table>

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:

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

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:

<table><tr><td colspan="2">Current or former Eversource Energy companies, segments or investments:</td></tr><tr><td>Eversource, ES or the Company</td><td>Eversource Energy and subsidiaries</td></tr><tr><td>Eversource parent or ES parent</td><td>Eversource Energy, a public utility holding company</td></tr><tr><td>ES parent and other companies</td><td>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&#x27;s equity ownership interests that are not consolidated</td></tr><tr><td>CL&amp;P</td><td>The Connecticut Light and Power Company</td></tr><tr><td>NSTAR Electric</td><td>NSTAR Electric Company</td></tr><tr><td>PSNH</td><td>Public Service Company of New Hampshire</td></tr><tr><td>PSNH Funding</td><td>PSNH Funding LLC 3, a bankruptcy remote, special purpose, wholly-owned subsidiary of PSNH</td></tr><tr><td>NSTAR Gas</td><td>NSTAR Gas Company</td></tr><tr><td>Yankee Gas</td><td>Yankee Gas Services Company</td></tr><tr><td>Aquarion</td><td>Eversource Aquarion Holdings, Inc. and its subsidiaries</td></tr><tr><td>NPT</td><td>Northern Pass Transmission LLC</td></tr><tr><td>Northern Pass</td><td>The HVDC and associated alternating-current transmission line project from Canada into New Hampshire</td></tr><tr><td>Eversource Service</td><td>Eversource Energy Service Company</td></tr><tr><td>Bay State Wind</td><td>Bay State Wind LLC, an offshore wind business being developed jointly by Eversource and Denmark-based</td></tr><tr><td>North East Offshore</td><td>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</td></tr><tr><td>CYAPC</td><td>Connecticut Yankee Atomic Power Company</td></tr><tr><td>MYAPC</td><td>Maine Yankee Atomic Power Company</td></tr><tr><td>YAEC</td><td>Yankee Atomic Electric Company</td></tr><tr><td>Yankee Companies</td><td>CYAPC, YAEC and MYAPC</td></tr><tr><td>Regulated companies</td><td>The Eversource regulated companies are comprised of the electric distribution and transmission businesses of CL&amp;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</td></tr><tr><td colspan="2">Regulators:</td></tr><tr><td>DEEP</td><td>Connecticut Department of Energy and Environmental Protection</td></tr><tr><td>DOE</td><td>U.S. Department of Energy</td></tr><tr><td>DOER</td><td>Massachusetts Department of Energy Resources</td></tr><tr><td>DPU</td><td>Massachusetts Department of Public Utilities</td></tr><tr><td>EPA</td><td>U.S. Environmental Protection Agency</td></tr><tr><td>FERC</td><td>Federal Energy Regulatory Commission</td></tr><tr><td>ISO-NE</td><td>ISO New England, Inc., the New England Independent System Operator</td></tr><tr><td>MA DEP</td><td>Massachusetts Department of Environmental Protection</td></tr><tr><td>NHPUC</td><td>New Hampshire Public Utilities Commission</td></tr><tr><td>PURA</td><td>Connecticut Public Utilities Regulatory Authority</td></tr><tr><td>SEC</td><td>U.S. Securities and Exchange Commission</td></tr><tr><td>SJC</td><td>Supreme Judicial Court of Massachusetts</td></tr><tr><td colspan="2">Other Terms and Abbreviations:</td></tr><tr><td>ADIT</td><td>Accumulated Deferred Income Taxes</td></tr><tr><td>AFUDC</td><td>Allowance For Funds Used During Construction</td></tr><tr><td>AOCI</td><td>Accumulated Other Comprehensive Income</td></tr><tr><td>ARO</td><td>Asset Retirement Obligation</td></tr><tr><td>Bcf</td><td>Billion cubic feet</td></tr><tr><td>C&amp;LM</td><td>Conservation and Load Management</td></tr><tr><td>CfD</td><td>Contract for Differences</td></tr><tr><td>CTA</td><td>Competitive Transition Assessment</td></tr><tr><td>CWIP</td><td>Construction Work in Progress</td></tr><tr><td>EDC</td><td>Electric distribution company</td></tr><tr><td>EDIT</td><td>Excess Deferred Income Taxes</td></tr><tr><td>EPS</td><td>Earnings Per Share</td></tr></table>



<table><tr><td>ERISA</td><td>Employee Retirement Income Security Act of 1974</td></tr><tr><td>ESOP</td><td>Employee Stock Ownership Plan</td></tr><tr><td>Eversource 2018 Form 10-K</td><td>The Eversource Energy and Subsidiaries 2018 combined Annual Report on Form 10-K as filed with the SEC</td></tr><tr><td>Fitch</td><td>Fitch Ratings</td></tr><tr><td>FMCC</td><td>Federally Mandated Congestion Charge</td></tr><tr><td>FTR</td><td>Financial Transmission Rights</td></tr><tr><td>GAAP</td><td>Accounting principles generally accepted in the United States of America</td></tr><tr><td>GSC</td><td>Generation Service Charge</td></tr><tr><td>GSRP</td><td>Greater Springfield Reliability Project</td></tr><tr><td>GWh</td><td>Gigawatt-Hours</td></tr><tr><td>HQ</td><td>Hydro-Québec, a corporation wholly-owned by the Québec government, including its divisions that produce, transmit and distribute electricity in Québec, Canada</td></tr><tr><td>HVDC</td><td>High-voltage direct current</td></tr><tr><td>Hydro Renewable Energy</td><td>Hydro Renewable Energy, Inc., a wholly-owned subsidiary of Hydro-Québec</td></tr><tr><td>IPP</td><td>Independent Power Producers</td></tr><tr><td>ISO-NE Tariff</td><td>ISO-NE FERC Transmission, Markets and Services Tariff</td></tr><tr><td>kV</td><td>Kilovolt</td></tr><tr><td>kVa</td><td>Kilovolt-ampere</td></tr><tr><td>kW</td><td>Kilowatt (equal to one thousand watts)</td></tr><tr><td>LBR</td><td>Lost Base Revenue</td></tr><tr><td>LNG</td><td>Liquefied natural gas</td></tr><tr><td>LRS</td><td>Supplier of last resort service</td></tr><tr><td>MG</td><td>Million gallons</td></tr><tr><td>MGP</td><td>Manufactured Gas Plant</td></tr><tr><td>MMBtu</td><td>One million British thermal units</td></tr><tr><td>MMcf</td><td>Million cubic feet</td></tr><tr><td>Moody&#x27;s</td><td>Moody&#x27;s Investors Services, Inc.</td></tr><tr><td>MW</td><td>Megawatt</td></tr><tr><td>MWh</td><td>Megawatt-Hours</td></tr><tr><td>NEEWS</td><td>New England East-West Solution</td></tr><tr><td>NETOs</td><td>New England Transmission Owners (including Eversource, National Grid and Avangrid)</td></tr><tr><td>OCI</td><td>Other Comprehensive Income/(Loss)</td></tr><tr><td>PAM</td><td>Pension and PBOP Rate Adjustment Mechanism</td></tr><tr><td>PBOP</td><td>Postretirement Benefits Other Than Pension</td></tr><tr><td>PBOP Plan</td><td>Postretirement Benefits Other Than Pension Plan</td></tr><tr><td>Pension Plan</td><td>Single uniform noncontributory defined benefit retirement plan</td></tr><tr><td>PPA</td><td>Power purchase agreement</td></tr><tr><td>RECs</td><td>Renewable Energy Certificates</td></tr><tr><td>Regulatory ROE</td><td>The average cost of capital method for calculating the return on equity related to the distribution business segment excluding the wholesale transmission segment</td></tr><tr><td>ROE</td><td>Return on Equity</td></tr><tr><td>RRBs</td><td>Rate Reduction Bonds or Rate Reduction Certificates</td></tr><tr><td>RSUs</td><td>Restricted share units</td></tr><tr><td>S&amp;P</td><td>Standard &amp; Poor&#x27;s Financial Services LLC</td></tr><tr><td>SBC</td><td>Systems Benefits Charge</td></tr><tr><td>SCRC</td><td>Stranded Cost Recovery Charge</td></tr><tr><td>SERP</td><td>Supplemental Executive Retirement Plans and non-qualified defined benefit retirement plans</td></tr><tr><td>SS</td><td>Standard service</td></tr><tr><td>TCAM</td><td>Transmission Cost Adjustment Mechanism</td></tr><tr><td>TSA</td><td>Transmission Service Agreement</td></tr><tr><td>UI</td><td>The United Illuminating Company</td></tr><tr><td>VIE</td><td>Variable Interest Entity</td></tr></table>



# 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 13

Item 1B. Unresolved Staff Comments 17

Item 2. Properties 18

Item 3. Legal Proceedings 20

Item 4. Mine Safety Disclosures 20

PART II

Item 5. Market for the Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities 21

Item 6. Selected Consolidated Financial Data 22

Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations 23

Item 7A. Quantitative and Qualitative Disclosures about Market Risk 42

Item 8. Financial Statements and Supplementary Data 43

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure 100

Item 9A. Controls and Procedures 100

Item 9B. Other Information 101

PART III

Item 10. Directors, Executive Officers and Corporate Governance 101

Item 11. Executive Compensation 102

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters 102

Item 13. Certain Relationships and Related Transactions, and Director Independence 103

Item 14. Principal Accountant Fees and Services 103

PART IV

Item 15. Exhibits and Financial Statement Schedules 104

Item 16. Form 10-K Summary 104

Signatures E-5



# 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.



# 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.



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.

## 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.

- 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.

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.

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 its 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.

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.

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.

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.

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.

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.

## 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.

## 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/searchderg/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.

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.

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 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 forensic 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. 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.



## Item 2. Properties

## Transmission and Distribution System

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

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

<table><tr><td rowspan="2"></td><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td><td colspan="2">PSNH</td></tr><tr><td>Distribution</td><td>Transmission</td><td>Distribution</td><td>Transmission</td><td>Distribution</td><td>Transmission</td></tr><tr><td>Number of substations owned</td><td>181</td><td>20</td><td>169</td><td>35</td><td>136</td><td>22</td></tr><tr><td>Transformer capacity (in kVa)</td><td>21,618,000</td><td>3,633,000</td><td>16,937,000</td><td>7,465,000</td><td>4,336,000</td><td>5,051,000</td></tr><tr><td>Overhead lines (in circuit miles)</td><td>16,942</td><td>1,675</td><td>11,427</td><td>1,247</td><td>12,199</td><td>1,041</td></tr><tr><td>Capacity range of overhead transmission lines (in kV)</td><td>N/A</td><td>69 to 345</td><td>N/A</td><td>69 to 345</td><td>N/A</td><td>115 to 345</td></tr><tr><td>Underground lines (in circuit miles)</td><td>6,722</td><td>137</td><td>9,076</td><td>268</td><td>1,966</td><td>1</td></tr><tr><td>Capacity range of underground transmission lines (in kV)</td><td>N/A</td><td>69 to 345</td><td>N/A</td><td>115 to 345</td><td>N/A</td><td>115</td></tr></table>

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

## 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:

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

** 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.



## 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.

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.

## 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.

Total Shareholder Return






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.

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

## 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)

<table><tr><td>(Thousands of Dollars, except percentages and common share information)</td><td>2019</td><td>2018</td><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Balance Sheet Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Property, Plant and Equipment, Net</td><td>$ 27,585,470</td><td>$ 25,610,428</td><td>$ 23,617,463</td><td>$ 21,350,510</td><td>$ 19,892,441</td></tr><tr><td>Total Assets</td><td>41,123,915</td><td>38,241,256</td><td>36,220,386</td><td>32,053,173</td><td>30,580,309</td></tr><tr><td>Common Shareholders&#x27; Equity</td><td>12,629,994</td><td>11,486,817</td><td>11,086,242</td><td>10,711,734</td><td>10,352,215</td></tr><tr><td>Noncontrolling Interest - Preferred Stock of Subsidiaries</td><td>155,570</td><td>155,570</td><td>155,570</td><td>155,568</td><td>155,568</td></tr><tr><td>Long-Term Debt (a)</td><td>14,098,239</td><td>13,086,062</td><td>12,325,520</td><td>9,603,237</td><td>9,034,457</td></tr><tr><td>Obligations Under Capital Leases (a)</td><td>10,516</td><td>10,735</td><td>9,898</td><td>8,924</td><td>8,222</td></tr><tr><td>Obligations Under Operating Leases (a)</td><td>49,966</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Income Statement Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Revenues</td><td>$ 8,526,470</td><td>$ 8,448,201</td><td>$ 7,751,952</td><td>$ 7,639,129</td><td>$ 7,954,827</td></tr><tr><td>Net Income</td><td>$ 916,572</td><td>$ 1,040,519</td><td>$ 995,515</td><td>$ 949,821</td><td>$ 886,004</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>7,519</td><td>7,519</td><td>7,519</td><td>7,519</td><td>7,515</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 909,053</td><td>$ 1,033,000</td><td>$ 987,996</td><td>$ 942,302</td><td>$ 878,485</td></tr><tr><td>Common Share Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Earnings Per Common Share</td><td>$ 2.83</td><td>$ 3.25</td><td>$ 3.11</td><td>$ 2.97</td><td>$ 2.77</td></tr><tr><td>Diluted Earnings Per Common Share</td><td>$ 2.81</td><td>$ 3.25</td><td>$ 3.11</td><td>$ 2.96</td><td>$ 2.76</td></tr><tr><td>Dividends Declared Per Common Share</td><td>$ 2.14</td><td>$ 2.02</td><td>$ 1.90</td><td>$ 1.78</td><td>$ 1.67</td></tr><tr><td>Market Price - Closing (end of year) (b)</td><td>$ 85.07</td><td>$ 65.04</td><td>$ 63.18</td><td>$ 55.23</td><td>$ 51.07</td></tr><tr><td>Book Value Per Common Share (end of year)</td><td>$ 38.29</td><td>$ 36.25</td><td>$ 34.98</td><td>$ 33.80</td><td>$ 32.64</td></tr><tr><td>Tangible Book Value Per Common Share (end of year) (c)</td><td>$ 24.86</td><td>$ 22.27</td><td>$ 21.00</td><td>$ 22.70</td><td>$ 21.54</td></tr><tr><td>Rate of Return Earned on Average Common Equity (%) (d)</td><td>7.5</td><td>9.2</td><td>9.1</td><td>9.0</td><td>8.7</td></tr><tr><td>Market-to-Book Ratio (end of year) (e)</td><td>2.2</td><td>1.8</td><td>1.8</td><td>1.6</td><td>1.6</td></tr></table>

(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.

CL&P Selected Financial Data (Unaudited) have been omitted from this report but are set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.



## 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.



- 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,

<table><tr><td rowspan="2">(Millions of Dollars, Except Per Share Amounts)</td><td colspan="3">2019</td><td colspan="3">2018</td><td colspan="3">2017</td></tr><tr><td colspan="2">Amount</td><td colspan="2">Per Share</td><td colspan="2">Amount</td><td colspan="2">Per Share</td><td>Per Share</td></tr><tr><td>Net Income Attributable to Common Shareholders (GAAP)</td><td>$</td><td>909.1</td><td>$</td><td>2.81</td><td>$</td><td>1,033.0</td><td>$</td><td>3.25</td><td>$</td></tr><tr><td>Regulated Companies</td><td>$</td><td>1,105.3</td><td>$</td><td>3.43</td><td>$</td><td>1,006.7</td><td>$</td><td>3.17</td><td>$</td></tr><tr><td>Eversource Parent and Other Companies</td><td></td><td>8.2</td><td></td><td>0.02</td><td></td><td>26.3</td><td></td><td>0.08</td><td></td></tr><tr><td>Non-GAAP Earnings</td><td>$</td><td>1,113.5</td><td>$</td><td>3.45</td><td>$</td><td>1,033.0</td><td>$</td><td>3.25</td><td>$</td></tr><tr><td>Impairment of Northern Pass Transmission (after-tax)</td><td></td><td>(204.4)</td><td></td><td>(0.64)</td><td></td><td>—</td><td></td><td>—</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders (GAAP)</td><td>$</td><td>909.1</td><td>$</td><td>2.81</td><td>$</td><td>1,033.0</td><td>$</td><td>3.25</td><td>$</td></tr></table>

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:

<table><tr><td rowspan="3">(Millions of Dollars, Except Per Share Amounts)</td><td colspan="7">For the Years Ended December 31,</td></tr><tr><td colspan="2">2019</td><td colspan="2">2018</td><td colspan="3">2017</td></tr><tr><td>Amount</td><td>Per Share</td><td>Amount</td><td>Per Share</td><td>Amount</td><td>Per Share</td><td></td></tr><tr><td>Net Income - Regulated Companies (GAAP)</td><td>$</td><td>900.9</td><td>$</td><td>2.79</td><td>$</td><td>1,006.7</td><td>$</td></tr><tr><td>Electric Distribution</td><td>$</td><td>513.3</td><td>$</td><td>1.59</td><td>$</td><td>455.4</td><td>$</td></tr><tr><td>Electric Transmission, excluding Northern Pass Transmission impairment (Non-GAAP)</td><td></td><td>460.9</td><td></td><td>1.43</td><td></td><td>427.2</td><td></td></tr><tr><td>Natural Gas Distribution</td><td></td><td>96.2</td><td></td><td>0.30</td><td></td><td>93.2</td><td></td></tr><tr><td>Water Distribution</td><td></td><td>34.9</td><td></td><td>0.11</td><td></td><td>30.9</td><td></td></tr><tr><td>Net Income - Regulated Companies (Non-GAAP)</td><td>$</td><td>1,105.3</td><td>$</td><td>3.43</td><td>$</td><td>1,006.7</td><td>$</td></tr><tr><td>Impairment of Northern Pass Transmission (after-tax)</td><td></td><td>(204.4)</td><td></td><td>(0.64)</td><td></td><td>—</td><td></td></tr><tr><td>Net Income - Regulated Companies (GAAP)</td><td>$</td><td>900.9</td><td>$</td><td>2.79</td><td>$</td><td>1,006.7</td><td>$</td></tr></table>

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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">Borrowings Outstanding as of December 31,</td><td colspan="3">Available Borrowing Capacity as of December 31,</td><td colspan="2">Weighted-Average Interest Rate as of December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2019</td><td>2018</td><td>2019</td><td>2018</td><td>2019</td><td></td></tr><tr><td>Eversource Parent Commercial Paper Program</td><td>$ 1,224.9</td><td>$ 631.5</td><td>$ 225.1</td><td>$ 818.5</td><td>1.98%</td><td>2.77%</td><td></td><td></td></tr><tr><td>NSTAR Electric Commercial Paper Program</td><td>10.5</td><td>278.5</td><td>639.5</td><td>371.5</td><td>1.63%</td><td>2.50%</td><td></td><td></td></tr></table>

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.

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:

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

(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.

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 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:

<table><tr><td rowspan="2"></td><td colspan="2">Moody&#x27;s</td><td colspan="2">S&amp;P</td><td colspan="2">Fitch</td></tr><tr><td>Current</td><td>Outlook</td><td>Current</td><td>Outlook</td><td>Current</td><td>Outlook</td></tr><tr><td>Eversource Parent</td><td>Baa1</td><td>Stable</td><td>A-</td><td>Stable</td><td>BBB+</td><td>Stable</td></tr><tr><td>CL&amp;P</td><td>A3</td><td>Stable</td><td>A</td><td>Stable</td><td>A-</td><td>Stable</td></tr><tr><td>NSTAR Electric</td><td>A1</td><td>Stable</td><td>A</td><td>Stable</td><td>A</td><td>Stable</td></tr><tr><td>PSNH</td><td>A3</td><td>Stable</td><td>A</td><td>Stable</td><td>A-</td><td>Stable</td></tr></table>

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:

<table><tr><td rowspan="2"></td><td colspan="2">Moody&#x27;s</td><td colspan="2">S&amp;P</td><td colspan="2">Fitch</td></tr><tr><td>Current</td><td>Outlook</td><td>Current</td><td>Outlook</td><td>Current</td><td>Outlook</td></tr><tr><td>Eversource Parent</td><td>Baa1</td><td>Stable</td><td>BBB+</td><td>Stable</td><td>BBB+</td><td>Stable</td></tr><tr><td>CL&amp;P</td><td>A1</td><td>Stable</td><td>A+</td><td>Stable</td><td>A+</td><td>Stable</td></tr><tr><td>NSTAR Electric</td><td>A1</td><td>Stable</td><td>A</td><td>Stable</td><td>A+</td><td>Stable</td></tr><tr><td>PSNH</td><td>A1</td><td>Stable</td><td>A+</td><td>Stable</td><td>A+</td><td>Stable</td></tr></table>

## 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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>CL&amp;P</td><td>$ 459.5</td><td>$ 465.5</td><td>$ 431.5</td></tr><tr><td>NSTAR Electric</td><td>379.7</td><td>334.3</td><td>301.9</td></tr><tr><td>PSNH</td><td>190.4</td><td>194.2</td><td>155.6</td></tr><tr><td>NPT</td><td>9.8</td><td>29.4</td><td>43.3</td></tr><tr><td>Total Electric Transmission Segment</td><td>$ 1,039.4</td><td>$ 1,023.4</td><td>$ 932.3</td></tr></table>

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.

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,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="9">For the Years Ended December 31,</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Total Electric</td><td>Natural Gas</td><td>Water (1)</td><td>Total</td><td></td><td></td></tr><tr><td>2019</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Business</td><td>$ 228.7</td><td>$ 201.0</td><td>$ 47.3</td><td>$ 477.0</td><td>$ 71.2</td><td>$ 15.0</td><td>$ 563.2</td><td></td><td></td></tr><tr><td>Aging Infrastructure</td><td>224.5</td><td>255.5</td><td>90.8</td><td>570.8</td><td>315.2</td><td>93.9</td><td>979.9</td><td></td><td></td></tr><tr><td>Load Growth and Other</td><td>59.6</td><td>89.4</td><td>16.8</td><td>165.8</td><td>66.8</td><td>1.5</td><td>234.1</td><td></td><td></td></tr><tr><td>Total Distribution</td><td>512.8</td><td>545.9</td><td>154.9</td><td>1,213.6</td><td>453.2</td><td>110.4</td><td>1,777.2</td><td></td><td></td></tr><tr><td>Solar</td><td>—</td><td>7.5</td><td>—</td><td>7.5</td><td>—</td><td>—</td><td>7.5</td><td></td><td></td></tr><tr><td>Total</td><td>$ 512.8</td><td>$ 553.4</td><td>$ 154.9</td><td>$ 1,221.1</td><td>$ 453.2</td><td>110.4</td><td>$ 1,784.7</td><td></td><td></td></tr><tr><td>2018</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Business</td><td>$ 256.3</td><td>$ 217.7</td><td>$ 69.3</td><td>$ 543.3</td><td>$ 72.9</td><td>$ 17.0</td><td>$ 633.2</td><td></td><td></td></tr><tr><td>Aging Infrastructure</td><td>151.6</td><td>133.3</td><td>73.0</td><td>357.9</td><td>280.2</td><td>81.1</td><td>719.2</td><td></td><td></td></tr><tr><td>Load Growth and Other</td><td>79.7</td><td>94.3</td><td>15.6</td><td>189.6</td><td>51.4</td><td>3.6</td><td>244.6</td><td></td><td></td></tr><tr><td>Total Distribution</td><td>487.6</td><td>445.3</td><td>157.9</td><td>1,090.8</td><td>404.5</td><td>101.7</td><td>1,597.0</td><td></td><td></td></tr><tr><td>Solar and Other</td><td>—</td><td>53.4</td><td>0.9</td><td>54.3</td><td>—</td><td>—</td><td>54.3</td><td></td><td></td></tr><tr><td>Total</td><td>$ 487.6</td><td>$ 498.7</td><td>$ 158.8</td><td>$ 1,145.1</td><td>$ 404.5</td><td>$ 101.7</td><td>$ 1,651.3</td><td></td><td></td></tr><tr><td>2017</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Business</td><td>$ 214.0</td><td>$ 166.1</td><td>$ 67.2</td><td>$ 447.3</td><td>$ 67.7</td><td>N/A</td><td>$ 515.0</td><td></td><td></td></tr><tr><td>Aging Infrastructure</td><td>180.7</td><td>95.4</td><td>87.8</td><td>363.9</td><td>219.9</td><td>N/A</td><td>583.8</td><td></td><td></td></tr><tr><td>Load Growth and Other</td><td>52.3</td><td>96.6</td><td>13.2</td><td>162.1</td><td>47.7</td><td>N/A</td><td>209.8</td><td></td><td></td></tr><tr><td>Total Distribution</td><td>447.0</td><td>358.1</td><td>168.2</td><td>973.3</td><td>335.3</td><td>N/A</td><td>1,308.6</td><td></td><td></td></tr><tr><td>Solar and Other</td><td>—</td><td>100.1</td><td>8.5</td><td>108.6</td><td>—</td><td>N/A</td><td>108.6</td><td></td><td></td></tr><tr><td>Total</td><td>$ 447.0</td><td>$ 458.2</td><td>$ 176.7</td><td>$ 1,081.9</td><td>$ 335.3</td><td>N/A</td><td>$ 1,417.2</td><td></td><td></td></tr></table>

(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 incidents 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.

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:

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

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:

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

(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.

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. 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.

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:

<table><tr><td>Eversource Utility and Jurisdiction</td><td>EDIT Refund Timing</td><td>Effective Date of January 1, 2018 Tax Rate Reflected in Rates</td></tr><tr><td>Connecticut</td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>Reflected in rates effective May 1, 2019</td><td>May 1, 2018</td></tr><tr><td>Yankee Gas</td><td>Reflected in rates effective November 15, 2018</td><td>November 15, 2018</td></tr><tr><td>Massachusetts</td><td></td><td></td></tr><tr><td>NSTAR Electric</td><td>Reflected in rates effective January 1, 2019</td><td>February 1, 2018</td></tr><tr><td>NSTAR Gas</td><td>Reflected in rates effective February 1, 2019</td><td>July 1, 2018</td></tr><tr><td>New Hampshire</td><td></td><td></td></tr><tr><td>PSNH</td><td>Refunds for EDIT are being addressed in permanent distribution rate case filing</td><td>July 1, 2019 for distribution</td></tr><tr><td></td><td>Refunds for EDIT related to PSNH&#x27;s divested generation assets reflected in rates effective August 1, 2018</td><td></td></tr><tr><td>Transmission</td><td></td><td></td></tr><tr><td>CL&amp;P, NSTAR Electric and PSNH</td><td>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.</td><td>January 1, 2018 for local transmission service and June 1, 2018 for regional transmission service</td></tr></table>

## 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.

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:

<table><tr><td>(Millions of Dollars)</td><td colspan="3">Increase in Pension Plan Cost</td><td colspan="3">Decrease in PBOP Plan Income</td></tr><tr><td>Assumption Change</td><td colspan="3">As of December 31,</td><td colspan="3">As of December 31,</td></tr><tr><td>Eversource</td><td>2019</td><td>2018</td><td></td><td>2019</td><td>2018</td><td></td></tr><tr><td>Lower expected long-term rate of return</td><td>$     22.9</td><td>$     23.7</td><td>$     4.1</td><td>$     4.5</td><td></td><td></td></tr><tr><td>Lower discount rate</td><td>21.7</td><td>25.5</td><td>1.7</td><td>2.9</td><td></td><td></td></tr><tr><td>Higher compensation rate</td><td>8.7</td><td>6.8</td><td>N/A</td><td>N/A</td><td></td><td></td></tr></table>

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.

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.

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.



## 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:

<table><tr><td>Eversource (Millions of Dollars)</td><td>2020</td><td>2021</td><td>2022</td><td>2023</td><td>2024</td><td>Thereafter</td><td>Total</td></tr><tr><td>Long-term debt maturities (a)</td><td>$ 296.1</td><td>$ 1,033.6</td><td>$ 1,188.9</td><td>$ 1,665.2</td><td>$ 1,049.8</td><td>$ 8,447.8</td><td>$ 13,681.4</td></tr><tr><td>Rate reduction bond maturities</td><td>43.2</td><td>43.2</td><td>43.2</td><td>43.2</td><td>43.3</td><td>367.3</td><td>583.3</td></tr><tr><td>Estimated interest payments on existing debt (b)</td><td>511.5</td><td>493.4</td><td>458.4</td><td>425.5</td><td>384.1</td><td>4,020.3</td><td>6,293.2</td></tr><tr><td>Operating leases (c)</td><td>10.2</td><td>9.0</td><td>7.4</td><td>4.9</td><td>2.8</td><td>28.9</td><td>63.2</td></tr><tr><td>Finance leases (c)</td><td>3.4</td><td>2.9</td><td>1.5</td><td>0.8</td><td>0.8</td><td>13.1</td><td>22.5</td></tr><tr><td>Funding of pension obligations (d) (e)</td><td>105.0</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>105.0</td></tr><tr><td>Funding of PBOP obligations (d) (e)</td><td>2.9</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>2.9</td></tr><tr><td>Estimated future annual long-term contractual costs (f)</td><td>998.8</td><td>941.6</td><td>946.5</td><td>897.5</td><td>881.9</td><td>4,785.2</td><td>9,451.5</td></tr><tr><td>Total (g)</td><td>$ 1,971.1</td><td>$ 2,523.7</td><td>$ 2,645.9</td><td>$ 3,037.1</td><td>$ 2,362.6</td><td>$ 17,662.6</td><td>$ 30,203.0</td></tr></table>

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

(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.



## 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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>Increase/(Decrease)</td></tr><tr><td>Operating Revenues</td><td>$ 8,526.5</td><td>$ 8,448.2</td><td>$ 78.3</td></tr><tr><td>Operating Expenses:</td><td></td><td></td><td></td></tr><tr><td>Purchased Power, Fuel and Transmission</td><td>3,040.2</td><td>3,139.0</td><td>(98.8)</td></tr><tr><td>Operations and Maintenance</td><td>1,363.1</td><td>1,335.2</td><td>27.9</td></tr><tr><td>Depreciation</td><td>885.3</td><td>819.9</td><td>65.4</td></tr><tr><td>Amortization</td><td>195.4</td><td>252.0</td><td>(56.6)</td></tr><tr><td>Energy Efficiency Programs</td><td>501.4</td><td>472.4</td><td>29.0</td></tr><tr><td>Taxes Other Than Income Taxes</td><td>711.0</td><td>729.8</td><td>(18.8)</td></tr><tr><td>Impairment of Northern Pass Transmission</td><td>239.6</td><td>—</td><td>239.6</td></tr><tr><td>Total Operating Expenses</td><td>6,936.0</td><td>6,748.3</td><td>187.7</td></tr><tr><td>Operating Income</td><td>1,590.5</td><td>1,699.9</td><td>(109.4)</td></tr><tr><td>Interest Expense</td><td>533.2</td><td>498.8</td><td>34.4</td></tr><tr><td>Other Income, Net</td><td>132.8</td><td>128.4</td><td>4.4</td></tr><tr><td>Income Before Income Tax Expense</td><td>1,190.1</td><td>1,329.5</td><td>(139.4)</td></tr><tr><td>Income Tax Expense</td><td>273.5</td><td>289.0</td><td>(15.5)</td></tr><tr><td>Net Income</td><td>916.6</td><td>1,040.5</td><td>(123.9)</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>7.5</td><td>7.5</td><td>—</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 909.1</td><td>$ 1,033.0</td><td>(123.9)</td></tr></table>

## 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:

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

(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:

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

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:

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

(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.

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:

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



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:

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

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.

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.

Results of Operations for the years ended December 31, 2019 and 2018 for each of CL&P, NSTAR Electric and PSNH have been omitted from this report but are set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.

## 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.



## 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

## 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



# 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



## 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.



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.



<table><tr><td rowspan="2">(Thousands of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2019</td><td>2018</td></tr><tr><td>ASSETS</td><td></td><td></td></tr><tr><td>Current Assets:</td><td></td><td></td></tr><tr><td>Cash</td><td>$ 15,432</td><td>$ 108,068</td></tr><tr><td>Receivables, Net</td><td>989,383</td><td>994,055</td></tr><tr><td>Unbilled Revenues</td><td>181,006</td><td>176,285</td></tr><tr><td>Fuel, Materials, Supplies and REC Inventory</td><td>235,471</td><td>238,042</td></tr><tr><td>Regulatory Assets</td><td>651,112</td><td>514,779</td></tr><tr><td>Prepayments and Other Current Assets</td><td>342,135</td><td>260,995</td></tr><tr><td>Total Current Assets</td><td>2,414,539</td><td>2,292,224</td></tr><tr><td>Property, Plant and Equipment, Net</td><td>27,585,470</td><td>25,610,428</td></tr><tr><td>Deferred Debits and Other Assets:</td><td></td><td></td></tr><tr><td>Regulatory Assets</td><td>4,863,639</td><td>4,631,137</td></tr><tr><td>Goodwill</td><td>4,427,266</td><td>4,427,266</td></tr><tr><td>Investments in Unconsolidated Affiliates</td><td>871,633</td><td>464,286</td></tr><tr><td>Marketable Securities</td><td>449,130</td><td>417,508</td></tr><tr><td>Other Long-Term Assets</td><td>512,238</td><td>398,407</td></tr><tr><td>Total Deferred Debits and Other Assets</td><td>11,123,906</td><td>10,338,604</td></tr><tr><td>Total Assets</td><td>$ 41,123,915</td><td>$ 38,241,256</td></tr><tr><td>LIABILITIES AND CAPITALIZATION</td><td></td><td></td></tr><tr><td>Current Liabilities:</td><td></td><td></td></tr><tr><td>Notes Payable</td><td>$ 889,084</td><td>$ 910,000</td></tr><tr><td>Long-Term Debt - Current Portion</td><td>327,411</td><td>837,319</td></tr><tr><td>Rate Reduction Bonds - Current Portion</td><td>43,210</td><td>52,332</td></tr><tr><td>Accounts Payable</td><td>1,147,872</td><td>1,119,995</td></tr><tr><td>Regulatory Liabilities</td><td>361,152</td><td>370,230</td></tr><tr><td>Other Current Liabilities</td><td>836,834</td><td>823,006</td></tr><tr><td>Total Current Liabilities</td><td>3,605,563</td><td>4,112,882</td></tr><tr><td>Deferred Credits and Other Liabilities:</td><td></td><td></td></tr><tr><td>Accumulated Deferred Income Taxes</td><td>3,755,777</td><td>3,506,030</td></tr><tr><td>Regulatory Liabilities</td><td>3,658,042</td><td>3,609,475</td></tr><tr><td>Derivative Liabilities</td><td>338,710</td><td>379,562</td></tr><tr><td>Asset Retirement Obligations</td><td>488,511</td><td>466,236</td></tr><tr><td>Accrued Pension, SERP and PBOP</td><td>1,370,245</td><td>962,510</td></tr><tr><td>Other Long-Term Liabilities</td><td>810,553</td><td>730,100</td></tr><tr><td>Total Deferred Credits and Other Liabilities</td><td>10,421,838</td><td>9,653,913</td></tr><tr><td>Long-Term Debt</td><td>13,770,828</td><td>12,248,743</td></tr><tr><td>Rate Reduction Bonds</td><td>540,122</td><td>583,331</td></tr><tr><td>Noncontrolling Interest - Preferred Stock of Subsidiaries</td><td>155,570</td><td>155,570</td></tr><tr><td>Common Shareholders&#x27; Equity:</td><td></td><td></td></tr><tr><td>Common Shares</td><td>1,729,292</td><td>1,669,392</td></tr><tr><td>Capital Surplus, Paid In</td><td>7,087,768</td><td>6,241,222</td></tr><tr><td>Retained Earnings</td><td>4,177,048</td><td>3,953,974</td></tr><tr><td>Accumulated Other Comprehensive Loss</td><td>(65,059)</td><td>(60,000)</td></tr><tr><td>Treasury Stock</td><td>(299,055)</td><td>(317,771)</td></tr><tr><td>Common Shareholders&#x27; Equity</td><td>12,629,994</td><td>11,486,817</td></tr><tr><td>Commitments and Contingencies (Note 13)</td><td></td><td></td></tr><tr><td>Total Liabilities and Capitalization</td><td>$ 41,123,915</td><td>$ 38,241,256</td></tr></table>

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



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

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

## CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

<table><tr><td rowspan="2">(Thousands of Dollars)</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>Net Income</td><td>$ 916,572</td><td>$ 1,040,519</td><td>$ 995,515</td></tr><tr><td>Other Comprehensive (Loss)/Income, Net of Tax:</td><td></td><td></td><td></td></tr><tr><td>Qualified Cash Flow Hedging Instruments</td><td>1,393</td><td>1,756</td><td>1,974</td></tr><tr><td>Changes in Unrealized Gains/(Losses) on Marketable Securities</td><td>1,166</td><td>(547)</td><td>(350)</td></tr><tr><td>Changes in Funded Status of Pension, SERP and PBOP Benefit Plans</td><td>(7,618)</td><td>5,194</td><td>(2,745)</td></tr><tr><td>Other Comprehensive (Loss)/Income, Net of Tax</td><td>(5,059)</td><td>6,403</td><td>(1,121)</td></tr><tr><td>Comprehensive Income Attributable to Noncontrolling Interests</td><td>(7,519)</td><td>(7,519)</td><td>(7,519)</td></tr><tr><td>Comprehensive Income Attributable to Common Shareholders</td><td>$ 903,994</td><td>$ 1,039,403</td><td>$ 986,875</td></tr></table>

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



## EVERSOURCE ENERGY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

<table><tr><td rowspan="2">(Thousands of Dollars, Except Share Information)</td><td colspan="2">Common Shares</td><td>Capital Surplus, Paid In</td><td>Retained Earnings</td><td>Accumulated Other Comprehensive Loss</td><td>Treasury Stock</td><td>Total Common Shareholders&#x27; Equity</td></tr><tr><td>Shares</td><td>Amount</td><td>$ 6,250,224</td><td>$ 3,175,171</td><td>$ (65,282)</td><td>$ (317,771)</td><td>$ 10,711,734</td></tr><tr><td>Balance as of January 1, 2017</td><td>316,885,808</td><td>$ 1,669,392</td><td>$ 6,250,224</td><td>$ 3,175,171</td><td>$ (65,282)</td><td>$ (317,771)</td><td>$ 10,711,734</td></tr><tr><td>Net Income</td><td></td><td></td><td></td><td>995,515</td><td></td><td></td><td>995,515</td></tr><tr><td>Dividends on Common Shares - $1.90 Per Share</td><td></td><td></td><td></td><td>(602,083)</td><td></td><td></td><td>(602,083)</td></tr><tr><td>Dividends on Preferred Stock</td><td></td><td></td><td></td><td>(7,519)</td><td></td><td></td><td>(7,519)</td></tr><tr><td>Long-Term Incentive Plan Activity</td><td></td><td></td><td>(10,834)</td><td></td><td></td><td></td><td>(10,834)</td></tr><tr><td>Other Changes in Shareholders&#x27; Equity</td><td></td><td></td><td>550</td><td></td><td></td><td></td><td>550</td></tr><tr><td>Other Comprehensive Loss</td><td></td><td></td><td></td><td></td><td>(1,121)</td><td></td><td>(1,121)</td></tr><tr><td>Balance as of December 31, 2017</td><td>316,885,808</td><td>1,669,392</td><td>6,239,940</td><td>3,561,084</td><td>(66,403)</td><td>(317,771)</td><td>11,086,242</td></tr><tr><td>Net Income</td><td></td><td></td><td></td><td>1,040,519</td><td></td><td></td><td>1,040,519</td></tr><tr><td>Dividends on Common Shares - $2.02 Per Share</td><td></td><td></td><td></td><td>(640,110)</td><td></td><td></td><td>(640,110)</td></tr><tr><td>Dividends on Preferred Stock</td><td></td><td></td><td></td><td>(7,519)</td><td></td><td></td><td>(7,519)</td></tr><tr><td>Long-Term Incentive Plan Activity</td><td></td><td></td><td>(543)</td><td></td><td></td><td></td><td>(543)</td></tr><tr><td>Other Changes in Shareholders&#x27; Equity</td><td></td><td></td><td>1,825</td><td></td><td></td><td></td><td>1,825</td></tr><tr><td>Other Comprehensive Income</td><td></td><td></td><td></td><td></td><td>6,403</td><td></td><td>6,403</td></tr><tr><td>Balance as of December 31, 2018</td><td>316,885,808</td><td>1,669,392</td><td>6,241,222</td><td>3,953,974</td><td>(60,000)</td><td>(317,771)</td><td>11,486,817</td></tr><tr><td>Net Income</td><td></td><td></td><td></td><td>916,572</td><td></td><td></td><td>916,572</td></tr><tr><td>Dividends on Common Shares - $2.14 Per Share</td><td></td><td></td><td></td><td>(685,979)</td><td></td><td></td><td>(685,979)</td></tr><tr><td>Dividends on Preferred Stock</td><td></td><td></td><td></td><td>(7,519)</td><td></td><td></td><td>(7,519)</td></tr><tr><td>Issuance of Common Shares - $5 par value</td><td>11,980,000</td><td>59,900</td><td>808,650</td><td></td><td></td><td></td><td>868,550</td></tr><tr><td>Long-Term Incentive Plan Activity</td><td></td><td></td><td>3,434</td><td></td><td></td><td></td><td>3,434</td></tr><tr><td>Issuance of Treasury Shares</td><td>1,014,837</td><td></td><td>50,758</td><td></td><td></td><td>18,716</td><td>69,474</td></tr><tr><td>Capital Stock Expense</td><td></td><td></td><td>(16,296)</td><td></td><td></td><td></td><td>(16,296)</td></tr><tr><td>Other Comprehensive Loss</td><td></td><td></td><td></td><td></td><td>(5,059)</td><td></td><td>(5,059)</td></tr><tr><td>Balance as of December 31, 2019</td><td>329,880,645</td><td>$ 1,729,292</td><td>$ 7,087,768</td><td>$ 4,177,048</td><td>$ (65,059)</td><td>$ (299,055)</td><td>$ 12,629,994</td></tr></table>

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



<table><tr><td colspan="4">(Thousands of Dollars)</td></tr><tr><td></td><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>Operating Activities:</td><td></td><td></td><td></td></tr><tr><td>Net Income</td><td>$     916,572</td><td>$     1,040,519</td><td>$     995,515</td></tr><tr><td>Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:</td><td></td><td></td><td></td></tr><tr><td>Depreciation</td><td>885,278</td><td>819,930</td><td>773,802</td></tr><tr><td>Deferred Income Taxes</td><td>209,812</td><td>174,812</td><td>491,630</td></tr><tr><td>Uncollectible Expense</td><td>63,446</td><td>61,337</td><td>44,453</td></tr><tr><td>Pension, SERP and PBOP Expense, Net</td><td>22,000</td><td>5,498</td><td>22,454</td></tr><tr><td>Pension and PBOP Contributions</td><td>(121,782)</td><td>(194,947)</td><td>(242,800)</td></tr><tr><td>Regulatory (Under)/Over Recoveries, Net</td><td>(124,870)</td><td>34,920</td><td>(47,935)</td></tr><tr><td>Amortization</td><td>195,380</td><td>252,026</td><td>89,986</td></tr><tr><td>Payments Related to CYAPC&#x27;s DOE Pre-1983 Spent Nuclear Fuel Obligation</td><td>(29,000)</td><td>(145,000)</td><td>—</td></tr><tr><td>Proceeds from DOE Spent Nuclear Fuel Litigation</td><td>68,840</td><td>—</td><td>—</td></tr><tr><td>Impairment of Northern Pass Transmission</td><td>239,644</td><td>—</td><td>—</td></tr><tr><td>Other</td><td>(196,087)</td><td>(111,225)</td><td>(204,421)</td></tr><tr><td>Changes in Current Assets and Liabilities:</td><td></td><td></td><td></td></tr><tr><td>Receivables and Unbilled Revenues, Net</td><td>(98,716)</td><td>(141,433)</td><td>(117,155)</td></tr><tr><td>Fuel, Materials, Supplies and REC Inventory</td><td>(8,074)</td><td>(831)</td><td>(9,223)</td></tr><tr><td>Taxes Receivable/Accrued, Net</td><td>(16,129)</td><td>(67,770)</td><td>52,284</td></tr><tr><td>Accounts Payable</td><td>14,866</td><td>24,481</td><td>56,067</td></tr><tr><td>Other Current Assets and Liabilities, Net</td><td>(11,603)</td><td>78,226</td><td>91,545</td></tr><tr><td>Net Cash Flows Provided by Operating Activities</td><td>2,009,577</td><td>1,830,543</td><td>1,996,202</td></tr><tr><td>Investing Activities:</td><td></td><td></td><td></td></tr><tr><td>Investments in Property, Plant and Equipment</td><td>(2,911,489)</td><td>(2,569,936)</td><td>(2,348,105)</td></tr><tr><td>Proceeds from Sales of Marketable Securities</td><td>566,592</td><td>900,749</td><td>832,903</td></tr><tr><td>Proceeds from Sales of Marketable Securities Used to Pay Pre-1983 Spent Nuclear Fuel Obligation</td><td>—</td><td>145,000</td><td>—</td></tr><tr><td>Purchases of Marketable Securities</td><td>(537,258)</td><td>(908,387)</td><td>(810,507)</td></tr><tr><td>Acquisition of Aquarion</td><td>—</td><td>—</td><td>(877,652)</td></tr><tr><td>Investments in Unconsolidated Affiliates, Net</td><td>(416,337)</td><td>(205,150)</td><td>(32,634)</td></tr><tr><td>Proceeds from the Sale of PSNH Generation Assets</td><td>—</td><td>193,924</td><td>—</td></tr><tr><td>Other Investing Activities</td><td>24,204</td><td>6,754</td><td>5,479</td></tr><tr><td>Net Cash Flows Used in Investing Activities</td><td>(3,274,288)</td><td>(2,437,046)</td><td>(3,230,516)</td></tr><tr><td>Financing Activities:</td><td></td><td></td><td></td></tr><tr><td>Issuance of Common Shares, Net of Issuance Costs</td><td>852,254</td><td>—</td><td>—</td></tr><tr><td>Cash Dividends on Common Shares</td><td>(663,239)</td><td>(640,110)</td><td>(602,083)</td></tr><tr><td>Cash Dividends on Preferred Stock</td><td>(7,519)</td><td>(7,519)</td><td>(7,519)</td></tr><tr><td>Increase/(Decrease) in Notes Payable</td><td>325,370</td><td>(379,310)</td><td>72,810</td></tr><tr><td>(Repayments)/Issuance of Rate Reduction Bonds</td><td>(52,332)</td><td>635,663</td><td>—</td></tr><tr><td>Issuance of Long-Term Debt</td><td>1,520,000</td><td>2,200,000</td><td>2,500,000</td></tr><tr><td>Retirement of Long-Term Debt</td><td>(801,078)</td><td>(1,050,330)</td><td>(745,000)</td></tr><tr><td>Other Financing Activities</td><td>(1,006)</td><td>(28,457)</td><td>(4,754)</td></tr><tr><td>Net Cash Flows Provided by Financing Activities</td><td>1,172,450</td><td>729,937</td><td>1,213,454</td></tr><tr><td>Net (Decrease)/Increase in Cash and Restricted Cash</td><td>(92,261)</td><td>123,434</td><td>(20,860)</td></tr><tr><td>Cash and Restricted Cash - Beginning of Year</td><td>209,324</td><td>85,890</td><td>106,750</td></tr><tr><td>Cash and Restricted Cash - End of Year</td><td>$     117,063</td><td>$     209,324</td><td>$     85,890</td></tr></table>

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

The 2019 financial statements for CL&P, NSTAR Electric and PSNH have been omitted from this report but are set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.



# 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.

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:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="4">Total Provision for Uncollectible Accounts</td><td colspan="4">Provision for Uncollectible Hardship Accounts</td></tr><tr><td colspan="4">As of December 31,</td><td colspan="4">As of December 31,</td></tr><tr><td>2019</td><td></td><td>2018</td><td></td><td>2019</td><td></td><td>2018</td><td></td></tr><tr><td>Eversource</td><td>$ 224.8</td><td>$ 212.7</td><td>$ 143.3</td><td>$ 131.5</td><td></td><td></td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>97.3</td><td>88.0</td><td>80.1</td><td>71.9</td><td></td><td></td><td></td><td></td></tr><tr><td>NSTAR Electric</td><td>75.4</td><td>74.5</td><td>43.9</td><td>42.5</td><td></td><td></td><td></td><td></td></tr><tr><td>PSNH</td><td>10.5</td><td>11.1</td><td>—</td><td>—</td><td></td><td></td><td></td><td></td></tr></table>

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

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td></tr><tr><td>Eversource</td><td>$ 63.4</td><td>$ 61.3</td><td>$ 44.5</td><td></td></tr><tr><td>CL&amp;P</td><td>15.9</td><td>15.8</td><td>5.3</td><td></td></tr><tr><td>NSTAR Electric</td><td>25.1</td><td>22.3</td><td>21.3</td><td></td></tr><tr><td>PSNH</td><td>6.7</td><td>6.4</td><td>6.7</td><td></td></tr></table>

## 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:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="10">As of December 31,</td></tr><tr><td colspan="4">2019</td><td colspan="6">2018</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PS NH</td><td></td></tr><tr><td>Fuel</td><td>$ 26.7</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ 33.1</td><td>$ —</td><td>$ —</td><td>$ —</td></tr><tr><td>Materials and Supplies</td><td>132.9</td><td>50.7</td><td>54.7</td><td>18.5</td><td>126.1</td><td>44.5</td><td>48.6</td><td>24.3</td><td></td></tr><tr><td>RECs</td><td>75.9</td><td>—</td><td>69.4</td><td>6.5</td><td>78.8</td><td>—</td><td>65.6</td><td>13.2</td><td></td></tr><tr><td>Total</td><td>$ 235.5</td><td>$ 50.7</td><td>$ 124.1</td><td>$ 25.0</td><td>$ 238.0</td><td>$ 44.5</td><td>$ 114.2</td><td>$ 37.5</td><td></td></tr></table>



## 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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td></tr><tr><td>Eversource - Natural Gas and Fuel</td><td>$ 462.1</td><td>$ 442.6</td><td>$ 432.5</td><td></td></tr><tr><td>PSNH - Fuel</td><td>—</td><td>7.9</td><td>43.4</td><td></td></tr></table>

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:

<table><tr><td rowspan="2">Eversource (Millions of Dollars, except percentages)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td></tr><tr><td>Borrowed Funds</td><td>$ 25.6</td><td>$ 19.7</td><td>$ 12.5</td><td></td></tr><tr><td>Equity Funds</td><td>45.0</td><td>44.0</td><td>34.4</td><td></td></tr><tr><td>Total AFUDC</td><td>$ 70.6</td><td>$ 63.7</td><td>$ 46.9</td><td></td></tr><tr><td>Average AFUDC Rate</td><td>5.4%</td><td>4.9%</td><td>5.1%</td><td></td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars, except percentages)</td><td colspan="4">2019</td><td colspan="4">2018</td><td colspan="4">2017</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp; P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Borrowed Funds</td><td>$ 7.1</td><td>$ 10.4</td><td>$ 2.8</td><td>$ 6.3</td><td>$ 7.8</td><td>$ 1.3</td><td>$ 5.1</td><td>$ 4.8</td><td>$ 0.7</td><td></td><td></td><td></td></tr><tr><td>Equity Funds</td><td>13.2</td><td>19.8</td><td>3.4</td><td>12.2</td><td>15.6</td><td>—</td><td>12.1</td><td>10.2</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Total AFUDC</td><td>$ 20.3</td><td>$ 30.2</td><td>$ 6.2</td><td>$ 18.5</td><td>$ 23.4</td><td>$ 1.3</td><td>$ 17.2</td><td>$ 15.0</td><td>$ 0.7</td><td></td><td></td><td></td></tr><tr><td>Average AFUDC Rate</td><td>6.3%</td><td>5.7%</td><td>4.6%</td><td>5.8%</td><td>5.0%</td><td>0.7%</td><td>6.2%</td><td>5.0%</td><td>0.7%</td><td></td><td></td><td></td></tr></table>

## M. Other Income, Net

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

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td></tr><tr><td>Pension, SERP and PBOP Non-Service Income Components</td><td>$ 31.3</td><td>$ 60.8</td><td>$ 29.9</td><td></td></tr><tr><td>AFUDC Equity</td><td>45.0</td><td>44.0</td><td>34.4</td><td></td></tr><tr><td>Equity in Earnings of Unconsolidated Affiliates (1)</td><td>42.2</td><td>3.8</td><td>27.4</td><td></td></tr><tr><td>Investment Income/(Loss)</td><td>0.8</td><td>(4.0)</td><td>7.5</td><td></td></tr><tr><td>Interest Income (2)</td><td>12.8</td><td>18.1</td><td>8.3</td><td></td></tr><tr><td>Gains on Sales of Property</td><td>0.3</td><td>5.1</td><td>—</td><td></td></tr><tr><td>Other</td><td>0.4</td><td>0.6</td><td>0.4</td><td></td></tr><tr><td>Total Other Income, Net</td><td>$ 132.8</td><td>$ 128.4</td><td>$ 107.9</td><td></td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">2019</td><td colspan="4">2018</td><td colspan="4">2017</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp; P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Pension, SERP and PBOP Non-Service Income Components</td><td>$ 0.5</td><td>$ 23.5</td><td>$ 4.9</td><td>$ 9.5</td><td>$ 36.0</td><td>$ 9.9</td><td>$ 1.8</td><td>$ 19.2</td><td>$ 5.9</td><td></td><td></td><td></td></tr><tr><td>AFUDC Equity</td><td>13.2</td><td>19.8</td><td>3.4</td><td>12.2</td><td>15.6</td><td>—</td><td>12.1</td><td>10.2</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Equity in Earnings of Unconsolidated Affiliates</td><td>0.1</td><td>0.7</td><td>—</td><td>0.1</td><td>0.7</td><td>—</td><td>—</td><td>0.3</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Investment Income/(Loss)</td><td>2.3</td><td>(0.4)</td><td>0.3</td><td>(3.0)</td><td>(0.5)</td><td>(0.8)</td><td>4.5</td><td>2.6</td><td>1.6</td><td></td><td></td><td></td></tr><tr><td>Interest Income (2)</td><td>1.5</td><td>0.7</td><td>10.5</td><td>3.7</td><td>0.8</td><td>14.1</td><td>4.6</td><td>1.8</td><td>2.2</td><td></td><td></td><td></td></tr><tr><td>Gains on Sales of Property</td><td>—</td><td>0.1</td><td>—</td><td>—</td><td>0.5</td><td>4.4</td><td>—</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Other</td><td>(0.1)</td><td>0.2</td><td>0.1</td><td>0.2</td><td>—</td><td>0.1</td><td>—</td><td>—</td><td>0.1</td><td></td><td></td><td></td></tr><tr><td>Total Other Income, Net</td><td>$ 17.5</td><td>$ 44.6</td><td>$ 19.2</td><td>$ 22.7</td><td>$ 53.1</td><td>$ 27.7</td><td>$ 23.0</td><td>$ 34.1</td><td>$ 9.8</td><td></td><td></td><td></td></tr></table>

(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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td></tr><tr><td>Eversource</td><td>$ 163.1</td><td>$ 161.9</td><td>$ 157.4</td><td></td></tr><tr><td>CL&amp;P</td><td>141.1</td><td>141.4</td><td>137.5</td><td></td></tr></table>

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

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="3">As of and For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>Cash Paid During the Year for:</td><td></td><td></td><td></td></tr><tr><td>Interest, Net of Amounts Capitalized</td><td>$ 532.4</td><td>$ 503.2</td><td>$ 419.1</td></tr><tr><td>Income Taxes</td><td>56.0</td><td>158.8</td><td>30.8</td></tr><tr><td>Non-Cash Investing Activities:</td><td></td><td></td><td></td></tr><tr><td>Plant Additions Included in Accounts Payable (As of) \( ^{(1)} \)</td><td>379.4</td><td>389.3</td><td>379.5</td></tr></table>

As of and For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">2019</td><td colspan="3">2018</td><td colspan="3">2017</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Cash Paid During the Year for:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Interest, Net of Amounts Capitalized</td><td>$ 144.6</td><td>$ 121.9</td><td>$ 56.9</td><td>$ 149.7</td><td>$ 122.1</td><td>$ 40.5</td><td>$ 144.6</td><td>$ 124.6</td><td>$ 45.9</td></tr><tr><td>Income Taxes</td><td>80.6</td><td>77.9</td><td>3.4</td><td>66.1</td><td>120.0</td><td>27.3</td><td>68.8</td><td>95.5</td><td>26.1</td></tr><tr><td>Non-Cash Investing Activities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Plant Additions Included in Accounts Payable (As of)  \( ^{(1)} \)</td><td>111.3</td><td>116.4</td><td>49.9</td><td>106.1</td><td>116.5</td><td>35.1</td><td>132.5</td><td>116.5</td><td>44.4</td></tr></table>

(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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="10">As of December 31,</td></tr><tr><td colspan="5">2019</td><td colspan="5">2018</td></tr><tr><td></td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td></td><td>PSNH</td><td></td></tr><tr><td>Cash as reported on the Balance Sheets</td><td>$ 15.4</td><td>$ —</td><td>$ 0.1</td><td>$ 0.4</td><td>$ 108.1</td><td>$ 87.7</td><td>$ 1.6</td><td>$ 1.4</td><td></td><td></td></tr><tr><td>Restricted cash included in:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Special Deposits</td><td>52.5</td><td>4.6</td><td>6.2</td><td>32.5</td><td>72.1</td><td>3.5</td><td>13.0</td><td>47.5</td><td></td><td></td></tr><tr><td>Marketable Securities</td><td>46.0</td><td>0.4</td><td>—</td><td>0.6</td><td>25.9</td><td>0.4</td><td>0.1</td><td>0.6</td><td></td><td></td></tr><tr><td>Other Long-Term Assets</td><td>3.2</td><td>—</td><td>—</td><td>3.2</td><td>3.2</td><td>—</td><td>—</td><td>3.2</td><td></td><td></td></tr><tr><td>Cash and Restricted Cash reported on the Statements of Cash Flows</td><td>$ 117.1</td><td>$ 5.0</td><td>$ 6.3</td><td>$ 36.7</td><td>$ 209.3</td><td>$ 91.6</td><td>$ 14.7</td><td>$ 52.7</td><td></td><td></td></tr></table>

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.

## 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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="6">2019</td><td colspan="5">2018</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSN</td><td></td><td></td><td></td></tr><tr><td>Benefit Costs</td><td>$ 2,382.9</td><td>$ 539.0</td><td>$ 629.8</td><td>$ 218.2</td><td>$ 1,914.8</td><td>$ 424.7</td><td>$ 544.4</td><td>$ 169.6</td><td></td><td></td><td></td></tr><tr><td>Income Taxes, Net</td><td>725.8</td><td>458.8</td><td>108.0</td><td>12.8</td><td>728.6</td><td>454.4</td><td>105.9</td><td>8.3</td><td></td><td></td><td></td></tr><tr><td>Securitized Stranded Costs</td><td>565.3</td><td>—</td><td>—</td><td>565.3</td><td>608.4</td><td>—</td><td>—</td><td>608.4</td><td></td><td></td><td></td></tr><tr><td>Storm Restoration Costs, Net</td><td>540.6</td><td>274.6</td><td>200.6</td><td>65.4</td><td>576.0</td><td>302.6</td><td>212.9</td><td>60.5</td><td></td><td></td><td></td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>411.5</td><td>78.3</td><td>207.1</td><td>65.8</td><td>316.0</td><td>33.2</td><td>169.1</td><td>67.3</td><td></td><td></td><td></td></tr><tr><td>Derivative Liabilities</td><td>334.5</td><td>329.2</td><td>—</td><td>—</td><td>356.5</td><td>356.5</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Goodwill-related</td><td>331.5</td><td>—</td><td>284.6</td><td>—</td><td>348.4</td><td>—</td><td>299.1</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Asset Retirement Obligations</td><td>97.2</td><td>30.8</td><td>50.3</td><td>3.6</td><td>89.2</td><td>32.3</td><td>42.2</td><td>3.3</td><td></td><td></td><td></td></tr><tr><td>Other Regulatory Assets</td><td>125.4</td><td>25.2</td><td>55.2</td><td>14.7</td><td>208.0</td><td>27.0</td><td>64.6</td><td>12.1</td><td></td><td></td><td></td></tr><tr><td>Total Regulatory Assets</td><td>5,514.7</td><td>1,735.9</td><td>1,535.6</td><td>945.8</td><td>5,145.9</td><td>1,630.7</td><td>1,438.2</td><td>929.5</td><td></td><td></td><td></td></tr><tr><td>Less: Current Portion</td><td>651.1</td><td>178.6</td><td>285.6</td><td>84.1</td><td>514.8</td><td>125.2</td><td>241.7</td><td>67.2</td><td></td><td></td><td></td></tr><tr><td>Total Long-Term Regulatory Assets</td><td>$ 4,863.6</td><td>$ 1,557.3</td><td>$ 1,250.0</td><td>$ 861.7</td><td>$ 4,631.1</td><td>$ 1,505.5</td><td>$ 1,196.5</td><td>$ 862.3</td><td></td><td></td><td></td></tr></table>

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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="9">As of December 31,</td></tr><tr><td colspan="4">2019</td><td colspan="5">2018</td></tr><tr><td></td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td></tr><tr><td>EDIT due to Tax Cuts and Jobs Act</td><td>$ 2,844.6</td><td>$ 1,022.8</td><td>$ 1,071.2</td><td>$ 392.8</td><td>$ 2,883.0</td><td>$ 1,031.0</td><td>$ 1,103.7</td><td>$ 396.4</td><td></td></tr><tr><td>Cost of Removal</td><td>559.8</td><td>64.6</td><td>330.6</td><td>16.3</td><td>521.0</td><td>39.9</td><td>307.1</td><td>22.1</td><td></td></tr><tr><td>Benefit Costs</td><td>84.5</td><td>—</td><td>72.2</td><td>—</td><td>91.2</td><td>—</td><td>76.9</td><td>—</td><td></td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>325.1</td><td>94.8</td><td>165.6</td><td>57.0</td><td>309.0</td><td>89.5</td><td>163.7</td><td>48.3</td><td></td></tr><tr><td>AFUDC - Transmission</td><td>73.2</td><td>46.0</td><td>27.2</td><td>—</td><td>70.7</td><td>47.4</td><td>23.3</td><td>—</td><td></td></tr><tr><td>Revenue Subject to Refund due to Tax Cuts and Jobs Act</td><td>14.6</td><td>—</td><td>—</td><td>6.0</td><td>24.6</td><td>—</td><td>—</td><td>12.6</td><td></td></tr><tr><td>Other Regulatory Liabilities</td><td>117.4</td><td>19.6</td><td>59.0</td><td>7.1</td><td>80.2</td><td>24.0</td><td>29.2</td><td>4.2</td><td></td></tr><tr><td>Total Regulatory Liabilities</td><td>4,019.2</td><td>1,247.8</td><td>1,725.8</td><td>479.2</td><td>3,979.7</td><td>1,231.8</td><td>1,703.9</td><td>483.6</td><td></td></tr><tr><td>Less: Current Portion</td><td>361.2</td><td>82.8</td><td>209.2</td><td>65.8</td><td>370.2</td><td>109.6</td><td>190.6</td><td>55.5</td><td></td></tr><tr><td>Total Long-Term Regulatory Liabilities</td><td>$ 3,658.0</td><td>$ 1,165.0</td><td>$ 1,516.6</td><td>$ 413.4</td><td>$ 3,609.5</td><td>$ 1,122.2</td><td>$ 1,513.3</td><td>$ 428.1</td><td></td></tr></table>

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 ADT 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.



## 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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2019</td><td>2018</td></tr><tr><td>Distribution - Electric</td><td>$ 15,880.0</td><td>$ 15,071.1</td></tr><tr><td>Distribution - Natural Gas</td><td>3,931.1</td><td>3,546.2</td></tr><tr><td>Transmission - Electric</td><td>10,958.4</td><td>10,153.9</td></tr><tr><td>Distribution - Water</td><td>1,726.5</td><td>1,639.8</td></tr><tr><td>Solar</td><td>200.2</td><td>164.1</td></tr><tr><td>Utility</td><td>32,696.2</td><td>30,575.1</td></tr><tr><td>Other (1)</td><td>1,025.6</td><td>778.6</td></tr><tr><td>Property, Plant and Equipment, Gross</td><td>33,721.8</td><td>31,353.7</td></tr><tr><td>Less: Accumulated Depreciation</td><td></td><td></td></tr><tr><td>Utility</td><td>(7,483.5)</td><td>(7,126.2)</td></tr><tr><td>Other</td><td>(387.4)</td><td>(336.7)</td></tr><tr><td>Total Accumulated Depreciation</td><td>(7,870.9)</td><td>(7,462.9)</td></tr><tr><td>Property, Plant and Equipment, Net</td><td>25,850.9</td><td>23,890.8</td></tr><tr><td>Construction Work in Progress</td><td>1,734.6</td><td>1,719.6</td></tr><tr><td>Total Property, Plant and Equipment, Net</td><td>$ 27,585.5</td><td>$ 25,610.4</td></tr></table>

As of December 31,

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

(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:

<table><tr><td>(Percent)</td><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>Eversource</td><td>3.0%</td><td>2.9%</td><td>3.0%</td></tr><tr><td>CL&amp;P</td><td>2.8%</td><td>2.8%</td><td>2.8%</td></tr><tr><td>NSTAR Electric</td><td>2.8%</td><td>2.8%</td><td>2.9%</td></tr><tr><td>PSNH</td><td>2.8%</td><td>2.8%</td><td>3.1%</td></tr></table>



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

As of December 31, 2019

<table><tr><td rowspan="2">(Years)</td><td colspan="4">As of December 31, 2019</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Distribution - Electric</td><td>34.3</td><td>35.3</td><td>33.7</td><td>33.2</td></tr><tr><td>Distribution - Natural Gas</td><td>43.2</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Transmission - Electric</td><td>40.4</td><td>36.8</td><td>44.9</td><td>42.1</td></tr><tr><td>Distribution - Water</td><td>33.5</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Solar</td><td>24.2</td><td>—</td><td>24.2</td><td>—</td></tr><tr><td>Other (1)</td><td>11.2</td><td>—</td><td>—</td><td>—</td></tr></table>

(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.

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,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td rowspan="2">Fair Value Hierarchy</td><td colspan="3">2019</td><td colspan="3">2018</td></tr><tr><td>Commodity Supply and Price Risk Management</td><td>Netting (1)</td><td>Net Amount Recorded as a Derivative</td><td>Commodity Supply and Price Risk Management</td><td>Netting (1)</td><td>Net Account Recorded as a Derivative</td></tr><tr><td>Current Derivative Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>Level 3</td><td>$ 12.2</td><td>$ (0.4)</td><td>$ 11.8</td><td>$ 9.6</td><td>$ (3.4)</td><td>$ 6.2</td></tr><tr><td>Other</td><td>Level 2</td><td>—</td><td>—</td><td>—</td><td>1.5</td><td>(0.9)</td><td>0.6</td></tr><tr><td>Long-Term Derivative Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>Level 3</td><td>67.5</td><td>(2.1)</td><td>65.4</td><td>74.2</td><td>(2.3)</td><td>71.9</td></tr><tr><td>Current Derivative Liabilities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>Level 3</td><td>(67.8)</td><td>—</td><td>(67.8)</td><td>(55.1)</td><td>—</td><td>(55.1)</td></tr><tr><td>Other</td><td>Level 2</td><td>(5.2)</td><td>—</td><td>(5.2)</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Long-Term Derivative Liabilities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>Level 3</td><td>(338.6)</td><td>—</td><td>(338.6)</td><td>(379.5)</td><td>—</td><td>(379.5)</td></tr><tr><td>Other</td><td>Level 2</td><td>(0.1)</td><td>—</td><td>(0.1)</td><td>—</td><td>—</td><td>—</td></tr></table>

(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 11, "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,

<table><tr><td rowspan="2">CL&amp;P</td><td colspan="4">2019</td><td colspan="4">2018</td></tr><tr><td colspan="3">Range</td><td>Period Covered</td><td colspan="3">Range</td><td>Period Covered</td></tr><tr><td>Capacity Prices</td><td>$ 3.01</td><td>- 7.34</td><td>per kW-Month</td><td>2023 - 2026</td><td>$ 4.30</td><td>- 7.44</td><td>per kW-Month</td><td>2022 - 2026</td></tr><tr><td>Forward Reserve</td><td>0.80</td><td>- 1.90</td><td>per kW-Month</td><td>2020 - 2024</td><td>0.75</td><td>- 1.78</td><td>per kW-Month</td><td>2019 - 2024</td></tr></table>

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.

<table><tr><td rowspan="2">CL&amp;P(Millions of Dollars)</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td></td></tr><tr><td>Derivatives, Net:</td><td></td><td></td><td></td></tr><tr><td>Fair Value as of Beginning of Period</td><td>$ (356.5)</td><td>$ (362.3)</td><td></td></tr><tr><td>Net Realized/Unrealized Losses Included in Regulatory Assets</td><td>(15.0)</td><td>(32.0)</td><td></td></tr><tr><td>Settlements</td><td>42.3</td><td>37.8</td><td></td></tr><tr><td>Fair Value as of End of Period</td><td>$ (329.2)</td><td>$ (356.5)</td><td></td></tr></table>

## 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,

<table><tr><td rowspan="2"></td><td colspan="6">2019</td><td colspan="5">2018</td></tr><tr><td colspan="2">Amortized Cost</td><td colspan="2">Pre-Tax Unrealized Gains</td><td colspan="2">Pre-Tax Unrealized Losses</td><td colspan="2">Fair Value</td><td colspan="2">Amortized Cost</td><td colspan="2">Pre-Tax Unrealized Gains</td></tr><tr><td>Debt Securities</td><td>$</td><td>228.4</td><td>$</td><td>5.8</td><td>$</td><td>(0.1)</td><td>$</td><td>234.1</td><td>$</td><td>190.0</td><td>$</td><td>(4.0)</td></tr></table>

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:

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

(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:

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="3">As of December 31,</td></tr><tr><td>2019</td><td>2018</td><td></td></tr><tr><td>Level 1:</td><td></td><td></td><td></td></tr><tr><td>Mutual Funds and Equities</td><td>$ 228.5</td><td>$ 244.0</td><td></td></tr><tr><td>Money Market Funds</td><td>46.0</td><td>25.9</td><td></td></tr><tr><td>Total Level 1</td><td>$ 274.5</td><td>$ 269.9</td><td></td></tr><tr><td>Level 2:</td><td></td><td></td><td></td></tr><tr><td>U.S. Government Issued Debt Securities (Agency and Treasury)</td><td>$ 96.8</td><td>$ 79.6</td><td></td></tr><tr><td>Corporate Debt Securities</td><td>44.0</td><td>39.5</td><td></td></tr><tr><td>Asset-Backed Debt Securities</td><td>12.9</td><td>14.0</td><td></td></tr><tr><td>Municipal Bonds</td><td>26.7</td><td>19.2</td><td></td></tr><tr><td>Other Fixed Income Securities</td><td>7.7</td><td>8.2</td><td></td></tr><tr><td>Total Level 2</td><td>$ 188.1</td><td>$ 160.5</td><td></td></tr><tr><td>Total Marketable Securities</td><td>$ 462.6</td><td>$ 430.4</td><td></td></tr></table>

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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td rowspan="2">Ownership Interest</td><td colspan="3">Investment Balance as of December 31,</td></tr><tr><td>2019</td><td>2018</td><td></td></tr><tr><td>Offshore Wind Business - North East Offshore and Bay State Wind</td><td>50%</td><td>$ 649.3</td><td>$ 234.3</td><td></td></tr><tr><td>Natural Gas Pipeline - Algonquin Gas Transmission, LLC</td><td>15%</td><td>127.8</td><td>155.0</td><td></td></tr><tr><td>Renewable Energy Investment Fund</td><td>90%</td><td>72.4</td><td>54.1</td><td></td></tr><tr><td>Other</td><td>various</td><td>22.1</td><td>20.9</td><td></td></tr><tr><td>Total Investments in Unconsolidated Affiliates</td><td></td><td>$ 871.6</td><td>$ 464.3</td><td></td></tr></table>

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.

## 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,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">2019</td><td colspan="5">2018</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PS NH</td><td></td></tr><tr><td>Balance as of Beginning of Year</td><td>$ 466.2</td><td>$ 33.5</td><td>$ 72.4</td><td>$ 4.0</td><td>$ 419.1</td><td>$ 31.5</td><td>$ 44.6</td><td>$ 25.0</td><td></td></tr><tr><td>Liabilities Incurred During the Year</td><td>30.3</td><td>—</td><td>30.3</td><td>—</td><td>11.3</td><td>—</td><td>11.3</td><td>—</td><td></td></tr><tr><td>Liabilities Settled During the Year</td><td>(21.3)</td><td>(3.6)</td><td>—</td><td>—</td><td>(36.6)</td><td>—</td><td>—</td><td>(21.5)</td><td></td></tr><tr><td>Accretion</td><td>27.1</td><td>2.2</td><td>3.5</td><td>0.2</td><td>25.5</td><td>2.0</td><td>2.2</td><td>0.5</td><td></td></tr><tr><td>Revisions in Estimated Cash Flows</td><td>(12.8)</td><td>(0.1)</td><td>(8.7)</td><td>—</td><td>46.9</td><td>—</td><td>14.3</td><td>—</td><td></td></tr><tr><td>Balance as of End of Year</td><td>$ 489.5</td><td>$ 32.0</td><td>$ 97.5</td><td>$ 4.2</td><td>$ 466.2</td><td>$ 33.5</td><td>$ 72.4</td><td>$ 4.0</td><td></td></tr></table>

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.

## 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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">Borrowings Outstanding as of December 31,</td><td colspan="3">Available Borrowing Capacity as of December 31,</td><td colspan="2">Weighted-Average Interest Rate as of December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2019</td><td>2018</td><td>2019</td><td>2018</td><td>2019</td><td></td></tr><tr><td>Eversource Parent Commercial Paper Program</td><td>$ 1,224.9</td><td>$ 631.5</td><td>$ 225.1</td><td>$ 818.5</td><td>1.98%</td><td>2.77%</td><td></td><td></td></tr><tr><td>NSTAR Electric Commercial Paper Program</td><td>10.5</td><td>278.5</td><td>639.5</td><td>371.5</td><td>1.63%</td><td>2.50%</td><td></td><td></td></tr></table>



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.

## 9. LONG-TERM DEBT

Details of long-term debt outstanding are as follows:

<table><tr><td rowspan="2">CL&amp;P
(Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2019</td><td>2018</td></tr><tr><td>First Mortgage Bonds:</td><td></td><td></td></tr><tr><td>7.875% 1994 Series D due 2024</td><td>$ 139.8</td><td>$ 139.8</td></tr><tr><td>5.750% 2004 Series B due 2034</td><td>130.0</td><td>130.0</td></tr><tr><td>5.625% 2005 Series B due 2035</td><td>100.0</td><td>100.0</td></tr><tr><td>6.350% 2006 Series A due 2036</td><td>250.0</td><td>250.0</td></tr><tr><td>5.750% 2007 Series B due 2037</td><td>150.0</td><td>150.0</td></tr><tr><td>6.375% 2007 Series D due 2037</td><td>100.0</td><td>100.0</td></tr><tr><td>5.500% 2009 Series A due 2019</td><td>—</td><td>250.0</td></tr><tr><td>2.500% 2013 Series A due 2023</td><td>400.0</td><td>400.0</td></tr><tr><td>4.300% 2014 Series A due 2044</td><td>475.0</td><td>475.0</td></tr><tr><td>4.150% 2015 Series A due 2045</td><td>350.0</td><td>350.0</td></tr><tr><td>3.200% 2017 Series A due 2027</td><td>500.0</td><td>300.0</td></tr><tr><td>4.000% 2018 Series A due 2048</td><td>800.0</td><td>500.0</td></tr><tr><td>Total First Mortgage Bonds</td><td>3,394.8</td><td>3,144.8</td></tr><tr><td>Pollution Control Revenue Bonds:</td><td></td><td></td></tr><tr><td>4.375% Fixed Rate Tax Exempt due 2028</td><td>120.5</td><td>120.5</td></tr><tr><td>Less Amounts due Within One Year</td><td>—</td><td>(250.0)</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>27.8</td><td>10.2</td></tr><tr><td>Unamortized Debt Issuance Costs</td><td>(25.0)</td><td>(21.5)</td></tr><tr><td>CL&amp;P Long-Term Debt</td><td>$ 3,518.1</td><td>$ 3,004.0</td></tr></table>



<table><tr><td rowspan="2">NSTAR Electric (Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2019</td><td>2018</td></tr><tr><td>Debentures:</td><td></td><td></td></tr><tr><td>5.750% due 2036</td><td>$ 200.0</td><td>$ 200.0</td></tr><tr><td>5.500% due 2040</td><td>300.0</td><td>300.0</td></tr><tr><td>2.375% due 2022</td><td>400.0</td><td>400.0</td></tr><tr><td>4.400% due 2044</td><td>300.0</td><td>300.0</td></tr><tr><td>3.250% due 2025</td><td>250.0</td><td>250.0</td></tr><tr><td>2.700% due 2026</td><td>250.0</td><td>250.0</td></tr><tr><td>3.200% due 2027</td><td>700.0</td><td>700.0</td></tr><tr><td>3.250% due 2029</td><td>400.0</td><td>—</td></tr><tr><td>Total Debentures</td><td>2,800.0</td><td>2,400.0</td></tr><tr><td>Notes:</td><td></td><td></td></tr><tr><td>5.900% Senior Notes Series B due 2034</td><td>50.0</td><td>50.0</td></tr><tr><td>6.700% Senior Notes Series D due 2037</td><td>40.0</td><td>40.0</td></tr><tr><td>5.100% Senior Notes Series E due 2020</td><td>95.0</td><td>95.0</td></tr><tr><td>3.500% Senior Notes Series F due 2021</td><td>250.0</td><td>250.0</td></tr><tr><td>3.880% Senior Notes Series G due 2023</td><td>80.0</td><td>80.0</td></tr><tr><td>2.750% Senior Notes Series H due 2026</td><td>50.0</td><td>50.0</td></tr><tr><td>Total Notes</td><td>565.0</td><td>565.0</td></tr><tr><td>Less Amounts due Within One Year</td><td>(95.0)</td><td>—</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>(4.1)</td><td>(2.5)</td></tr><tr><td>Unamortized Debt Issuance Costs</td><td>(18.8)</td><td>(17.7)</td></tr><tr><td>NSTAR Electric Long-Term Debt</td><td>$ 3,247.1</td><td>$ 2,944.8</td></tr></table>

<table><tr><td rowspan="2">PSNH (Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2019</td><td>2018</td></tr><tr><td>First Mortgage Bonds:</td><td></td><td></td></tr><tr><td>5.600% Series M due 2035</td><td>$ 50.0</td><td>$ 50.0</td></tr><tr><td>4.500% Series P due 2019</td><td>—</td><td>150.0</td></tr><tr><td>4.050% Series Q due 2021</td><td>122.0</td><td>122.0</td></tr><tr><td>3.200% Series R due 2021</td><td>160.0</td><td>160.0</td></tr><tr><td>3.500% Series S due 2023</td><td>325.0</td><td>325.0</td></tr><tr><td>3.600% Series T due 2049</td><td>300.0</td><td>—</td></tr><tr><td>Total First Mortgage Bonds</td><td>957.0</td><td>807.0</td></tr><tr><td>Less Amounts due Within One Year</td><td>—</td><td>(150.0)</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>(0.7)</td><td>—</td></tr><tr><td>Unamortized Debt Issuance Costs</td><td>(4.7)</td><td>(1.8)</td></tr><tr><td>PSNH Long-Term Debt</td><td>$ 951.6</td><td>$ 655.2</td></tr></table>



<table><tr><td rowspan="2">OTHER(Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2019</td><td>2018</td></tr><tr><td>Yankee Gas - First Mortgage Bonds: 2.230% - 8.480% due 2020 - 2049</td><td>$ 620.0</td><td>$ 470.0</td></tr><tr><td>NSTAR Gas - First Mortgage Bonds: 3.740% - 9.950% due 2020 - 2049</td><td>460.0</td><td>385.0</td></tr><tr><td>Aquarion - Senior Note 4.000% due 2024</td><td>360.0</td><td>360.0</td></tr><tr><td>Aquarion - Unsecured Notes 0% - 6.430% due 2021 - 2049</td><td>335.3</td><td>289.5</td></tr><tr><td>Aquarion - Secured Debt 4.100% - 9.640% due 2021 - 2035</td><td>68.8</td><td>70.7</td></tr><tr><td>Eversource Parent - Debentures 4.500% due 2019</td><td>—</td><td>350.0</td></tr><tr><td>Eversource Parent - Senior Notes 2.500% - 4.250% due 2021 - 2029</td><td>4,000.0</td><td>4,000.0</td></tr><tr><td>Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)</td><td>11.6</td><td>39.5</td></tr><tr><td>Fair Value Adjustment \( ^{(1)} \)</td><td>109.1</td><td>144.7</td></tr><tr><td>Less Fair Value Adjustment - Current Portion  \( ^{(1)} \)</td><td>(31.3)</td><td>(36.2)</td></tr><tr><td>Less Amounts due in One Year</td><td>(201.1)</td><td>(401.1)</td></tr><tr><td>Commercial Paper Classified as Long-Term Debt (See Note 8, Short-Term Debt)</td><td>346.3</td><td>—</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>(4.1)</td><td>(4.2)</td></tr><tr><td>Unamortized Debt Issuance Costs</td><td>(20.6)</td><td>(23.2)</td></tr><tr><td>Total Other Long-Term Debt</td><td>$ 6,054.0</td><td>$ 5,644.7</td></tr><tr><td>Total Eversource Long-Term Debt</td><td>$ 13,770.8</td><td>$ 12,248.7</td></tr></table>

(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:

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

(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:

<table><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>2020</td><td>$ 296.1</td><td>$ —</td><td>95.0</td><td>$ —</td></tr><tr><td>2021</td><td>1,033.6</td><td>—</td><td>250.0</td><td>282.0</td></tr><tr><td>2022</td><td>1,188.9</td><td>—</td><td>400.0</td><td>—</td></tr><tr><td>2023</td><td>1,665.2</td><td>400.0</td><td>80.0</td><td>325.0</td></tr><tr><td>2024</td><td>1,049.8</td><td>139.8</td><td>—</td><td>—</td></tr><tr><td>Thereafter</td><td>8,447.8</td><td>2,975.5</td><td>2,540.0</td><td>350.0</td></tr><tr><td>Total</td><td>$ 13,681.4</td><td>$ 3,515.3</td><td>$ 3,365.0</td><td>$ 957.0</td></tr></table>



## 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:

<table><tr><td colspan="3">(Millions of Dollars)</td></tr><tr><td>Balance Sheet:</td><td>As of December 31, 2019</td><td>As of December 31, 2018</td></tr><tr><td>Restricted Cash - Current Portion (included in Current Assets)</td><td>$ 32.5</td><td>$ 47.5</td></tr><tr><td>Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)</td><td>3.2</td><td>3.2</td></tr><tr><td>Securitized Stranded Cost (included in Regulatory Assets)</td><td>565.3</td><td>608.4</td></tr><tr><td>Other Regulatory Liabilities (included in Regulatory Liabilities)</td><td>5.6</td><td>5.8</td></tr><tr><td>Accrued Interest (included in Other Current Liabilities)</td><td>8.6</td><td>14.4</td></tr><tr><td>Rate Reduction Bonds - Current Portion</td><td>43.2</td><td>52.3</td></tr><tr><td>Rate Reduction Bonds - Long-Term Portion</td><td>540.1</td><td>583.3</td></tr><tr><td>(Millions of Dollars)</td><td>For the Year Ended December 31, 2019</td><td>For the Year Ended December 31, 2018</td></tr><tr><td>Income Statement:</td><td></td><td></td></tr><tr><td>Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)</td><td>$ 43.0</td><td>$ 27.3</td></tr><tr><td>Interest Expense on RRB Principal (included in Interest Expense)</td><td>21.1</td><td>14.4</td></tr></table>

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:

<table><tr><td rowspan="4">(Millions of Dollars)</td><td colspan="9">Pension and SERP</td></tr><tr><td colspan="9">As of December 31,</td></tr><tr><td colspan="5">2019</td><td colspan="4">2018</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSN</td><td></td></tr><tr><td>Change in Benefit Obligation:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Benefit Obligation as of Beginning of Year</td><td>$ (5,520.0)</td><td>$ (1,160.4)</td><td>$ (1,236.5)</td><td>$ (610.7)</td><td>$ (5,936.5)</td><td>$ (1,275.2)</td><td>$ (1,351.0)</td><td>$ (642.2)</td><td></td></tr><tr><td>Service Cost</td><td>(67.7)</td><td>(18.0)</td><td>(14.6)</td><td>(7.1)</td><td>(84.8)</td><td>(21.4)</td><td>(17.4)</td><td>(11.2)</td><td></td></tr><tr><td>Interest Cost</td><td>(219.0)</td><td>(45.7)</td><td>(49.0)</td><td>(24.0)</td><td>(196.4)</td><td>(41.8)</td><td>(43.5)</td><td>(22.0)</td><td></td></tr><tr><td>Actuarial Gain/(Loss)</td><td>(815.3)</td><td>(176.6)</td><td>(181.0)</td><td>(84.5)</td><td>414.9</td><td>106.1</td><td>98.6</td><td>39.2</td><td></td></tr><tr><td>Benefits Paid - Pension</td><td>273.0</td><td>60.2</td><td>67.1</td><td>30.3</td><td>261.8</td><td>59.6</td><td>66.9</td><td>26.2</td><td></td></tr><tr><td>Benefits Paid - Lump Sum</td><td>20.0</td><td>—</td><td>12.9</td><td>—</td><td>14.2</td><td>—</td><td>7.1</td><td>—</td><td></td></tr><tr><td>Benefits Paid - SERP</td><td>7.3</td><td>0.3</td><td>0.1</td><td>0.4</td><td>6.8</td><td>0.3</td><td>0.3</td><td>0.2</td><td></td></tr><tr><td>Employee Transfers</td><td>—</td><td>8.9</td><td>3.7</td><td>3.0</td><td>—</td><td>12.0</td><td>2.5</td><td>(0.9)</td><td></td></tr><tr><td>Benefit Obligation as of End of Year</td><td>$ (6,321.7)</td><td>$ (1,331.3)</td><td>$ (1,397.3)</td><td>$ (692.6)</td><td>$ (5,520.0)</td><td>$ (1,160.4)</td><td>$ (1,236.5)</td><td>$ (610.7)</td><td></td></tr><tr><td>Change in Pension Plan Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Fair Value of Pension Plan Assets as of Beginning of Year</td><td>$ 4,573.9</td><td>$ 918.4</td><td>$ 1,222.1</td><td>$ 506.6</td><td>$ 4,739.5</td><td>$ 963.0</td><td>$ 1,260.8</td><td>$ 539.5</td><td></td></tr><tr><td>Employer Contributions</td><td>112.5</td><td>24.0</td><td>0.4</td><td>15.4</td><td>185.6</td><td>41.2</td><td>56.5</td><td>—</td><td></td></tr><tr><td>Actual Return on Pension Plan Assets</td><td>575.2</td><td>112.9</td><td>150.0</td><td>62.9</td><td>(75.2)</td><td>(14.2)</td><td>(18.7)</td><td>(7.6)</td><td></td></tr><tr><td>Benefits Paid - Pension</td><td>(273.0)</td><td>(60.2)</td><td>(67.1)</td><td>(30.3)</td><td>(261.8)</td><td>(59.6)</td><td>(66.9)</td><td>(26.2)</td><td></td></tr><tr><td>Benefits Paid - Lump Sum</td><td>(20.0)</td><td>—</td><td>(12.9)</td><td>—</td><td>(14.2)</td><td>—</td><td>(7.1)</td><td>—</td><td></td></tr><tr><td>Employee Transfers</td><td>—</td><td>(8.9)</td><td>(3.7)</td><td>(3.0)</td><td>—</td><td>(12.0)</td><td>(2.5)</td><td>0.9</td><td></td></tr><tr><td>Fair Value of Pension Plan Assets as of End of Year</td><td>$ 4,968.6</td><td>$ 986.2</td><td>$ 1,288.8</td><td>$ 551.6</td><td>$ 4,573.9</td><td>$ 918.4</td><td>$ 1,222.1</td><td>$ 506.6</td><td></td></tr><tr><td>Funded Status as of December 31st</td><td>$ (1,353.1)</td><td>$ (345.1)</td><td>$ (108.5)</td><td>$ (141.0)</td><td>$ (946.1)</td><td>$ (242.0)</td><td>$ (14.4)</td><td>$ (104.1)</td><td></td></tr></table>

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:

<table><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>2019</td><td>$ 5,963.4</td><td>$ 1,205.4</td><td>$ 1,340.8</td><td>$ 646.7</td></tr><tr><td>2018</td><td>5,070.8</td><td>1,031.0</td><td>1,144.7</td><td>543.1</td></tr></table>



<table><tr><td rowspan="4">(Millions of Dollars)</td><td colspan="10">PBOP</td></tr><tr><td colspan="10">As of December 31,</td></tr><tr><td colspan="5">2019</td><td colspan="5">2018</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSN</td><td></td><td></td></tr><tr><td>Change in Benefit Obligation:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Benefit Obligation as of Beginning of Year</td><td>$ (841.5)</td><td>$ (161.7)</td><td>$ (246.3)</td><td>$ (91.9)</td><td>$ (948.6)</td><td>$ (178.4)</td><td>$ (278.6)</td><td>$ (101.1)</td><td></td><td></td></tr><tr><td>Service Cost</td><td>(7.8)</td><td>(1.4)</td><td>(1.7)</td><td>(0.7)</td><td>(10.0)</td><td>(1.9)</td><td>(2.0)</td><td>(1.1)</td><td></td><td></td></tr><tr><td>Interest Cost</td><td>(32.7)</td><td>(6.3)</td><td>(9.5)</td><td>(3.4)</td><td>(30.7)</td><td>(5.8)</td><td>(8.7)</td><td>(3.4)</td><td></td><td></td></tr><tr><td>Actuarial Gain/(Loss)</td><td>(67.0)</td><td>(13.4)</td><td>(15.2)</td><td>(3.1)</td><td>102.5</td><td>14.4</td><td>28.4</td><td>8.6</td><td></td><td></td></tr><tr><td>Benefits Paid</td><td>50.0</td><td>10.8</td><td>15.4</td><td>5.6</td><td>45.3</td><td>10.1</td><td>14.5</td><td>4.9</td><td></td><td></td></tr><tr><td>Employee Transfers</td><td>—</td><td>(0.7)</td><td>(1.0)</td><td>0.5</td><td>—</td><td>(0.1)</td><td>0.1</td><td>0.2</td><td></td><td></td></tr><tr><td>Benefit Obligation as of End of Year</td><td>$ (899.0)</td><td>$ (172.7)</td><td>$ (258.3)</td><td>$ (93.0)</td><td>$ (841.5)</td><td>$ (161.7)</td><td>$ (246.3)</td><td>$ (91.9)</td><td></td><td></td></tr><tr><td>Change in Plan Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Fair Value of Plan Assets as of Beginning of Year</td><td>$ 849.6</td><td>$ 120.6</td><td>$ 379.1</td><td>$ 71.2</td><td>$ 922.2</td><td>$ 135.9</td><td>$ 405.5</td><td>$ 79.0</td><td></td><td></td></tr><tr><td>Actual Return on Plan Assets</td><td>127.0</td><td>17.1</td><td>57.0</td><td>10.0</td><td>(36.6)</td><td>(5.2)</td><td>(17.4)</td><td>(2.9)</td><td></td><td></td></tr><tr><td>Employer Contributions</td><td>9.3</td><td>—</td><td>6.0</td><td>—</td><td>9.3</td><td>—</td><td>5.2</td><td>—</td><td></td><td></td></tr><tr><td>Benefits Paid</td><td>(50.0)</td><td>(10.8)</td><td>(15.4)</td><td>(5.6)</td><td>(45.3)</td><td>(10.1)</td><td>(14.5)</td><td>(4.9)</td><td></td><td></td></tr><tr><td>Employee Transfers</td><td>—</td><td>(0.6)</td><td>(2.3)</td><td>0.4</td><td>—</td><td>—</td><td>0.3</td><td>—</td><td></td><td></td></tr><tr><td>Fair Value of Plan Assets as of End of Year</td><td>$ 935.9</td><td>$ 126.3</td><td>$ 424.4</td><td>$ 76.0</td><td>$ 849.6</td><td>$ 120.6</td><td>$ 379.1</td><td>$ 71.2</td><td></td><td></td></tr><tr><td>Funded Status as of December 31st</td><td>$ 36.9</td><td>$ (46.4)</td><td>$ 166.1</td><td>$ (17.0)</td><td>$ 8.1</td><td>$ (41.1)</td><td>$ 132.8</td><td>$ (20.7)</td><td></td><td></td></tr></table>

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:

<table><tr><td rowspan="3"></td><td colspan="3">Pension and SERP</td><td colspan="3">PBOP</td></tr><tr><td colspan="3">As of December 31,</td><td colspan="3">As of December 31,</td></tr><tr><td colspan="2">2019</td><td>2018</td><td>2019</td><td colspan="2">2018</td></tr><tr><td>Discount Rate</td><td>3.04%</td><td>3.35%</td><td>4.22%</td><td>4.45%</td><td>3.26%</td><td>4.38%</td></tr><tr><td>Compensation/Progression Rate</td><td>3.50%</td><td>4.00%</td><td>3.50%</td><td>4.00%</td><td colspan="2">N/A</td></tr></table>

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.



<table><tr><td rowspan="2"></td><td colspan="6">Pension and SERP</td><td colspan="6">PBOP</td></tr><tr><td colspan="6">For the Year Ended December 31, 2019</td><td colspan="6">For the Year Ended December 31, 2019</td></tr><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td></td><td>PSNH</td><td></td><td></td><td></td></tr><tr><td>Service Cost</td><td>$   67.7</td><td>$   18.0</td><td>$   14.6</td><td>$   7.1</td><td>$   7.8</td><td>$   1.4</td><td>$   1.7</td><td>$   0.7</td><td></td><td></td><td></td><td></td></tr><tr><td>Interest Cost</td><td>219.0</td><td>45.7</td><td>49.0</td><td>24.0</td><td>32.7</td><td>6.3</td><td>9.5</td><td>3.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(367.1)</td><td>(73.2)</td><td>(97.1)</td><td>(40.7)</td><td>(66.8)</td><td>(9.2)</td><td>(30.2)</td><td>(5.4)</td><td></td><td></td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>143.2</td><td>26.9</td><td>44.7</td><td>10.6</td><td>8.3</td><td>1.3</td><td>3.3</td><td>0.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Prior Service Cost/(Credit)</td><td>0.9</td><td>—</td><td>0.3</td><td>—</td><td>(23.5)</td><td>1.1</td><td>(16.9)</td><td>0.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Total Net Periodic Benefit Expense/(Income)</td><td>$   63.7</td><td>$   17.4</td><td>$   11.5</td><td>$   1.0</td><td>$    (41.5)</td><td>$   0.9</td><td>$    (32.6)</td><td>$    (0.6)</td><td></td><td></td><td></td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$   8.5</td><td>$   8.0</td><td>$   2.3</td><td>N/A</td><td>$    (0.9)</td><td>$    (1.2)</td><td>$    (0.4)</td><td></td><td></td><td></td><td></td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="6">Pension and SERP</td><td colspan="6">PBOP</td></tr><tr><td colspan="6">For the Year Ended December 31, 2018</td><td colspan="6">For the Year Ended December 31, 2018</td></tr><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td></td><td>PSNH</td><td></td><td></td><td></td></tr><tr><td>Service Cost</td><td>$   84.8</td><td>$   21.4</td><td>$   17.4</td><td>$   11.2</td><td>$   10.0</td><td>$   1.9</td><td>$   2.0</td><td>$   1.1</td><td></td><td></td><td></td><td></td></tr><tr><td>Interest Cost</td><td>196.4</td><td>41.8</td><td>43.5</td><td>22.0</td><td>30.7</td><td>5.8</td><td>8.7</td><td>3.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(391.6)</td><td>(79.1)</td><td>(104.9)</td><td>(43.6)</td><td>(72.4)</td><td>(10.4)</td><td>(32.5)</td><td>(6.0)</td><td></td><td></td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>145.7</td><td>29.1</td><td>41.1</td><td>11.6</td><td>10.3</td><td>1.6</td><td>2.3</td><td>0.7</td><td></td><td></td><td></td><td></td></tr><tr><td>Prior Service Cost/(Credit)</td><td>4.3</td><td>1.1</td><td>0.2</td><td>0.4</td><td>(23.6)</td><td>1.1</td><td>(16.9)</td><td>0.5</td><td></td><td></td><td></td><td></td></tr><tr><td>Total Net Periodic Benefit Expense/(Income)</td><td>$   39.6</td><td>$   14.3</td><td>$    (2.7)</td><td>$   1.6</td><td>$    (45.0)</td><td>$    —</td><td>$    (36.4)</td><td>$    (0.3)</td><td></td><td></td><td></td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$   6.1</td><td>$   6.5</td><td>$   1.9</td><td>N/A</td><td>$    (1.0)</td><td>$    (1.3)</td><td>$    (0.4)</td><td></td><td></td><td></td><td></td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="6">Pension and SERP</td><td colspan="6">PBOP</td></tr><tr><td colspan="6">For the Year Ended December 31, 2017</td><td colspan="6">For the Year Ended December 31, 2017</td></tr><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td></td><td>PSNH</td><td></td><td></td><td></td></tr><tr><td>Service Cost</td><td>$   71.3</td><td>$   18.5</td><td>$   15.5</td><td>$   9.7</td><td>$   9.5</td><td>$   1.9</td><td>$   1.7</td><td>$   1.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Interest Cost</td><td>188.0</td><td>41.6</td><td>42.7</td><td>21.2</td><td>27.1</td><td>5.3</td><td>8.7</td><td>3.0</td><td></td><td></td><td></td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(334.1)</td><td>(71.7)</td><td>(87.6)</td><td>(40.0)</td><td>(63.7)</td><td>(9.7)</td><td>(28.6)</td><td>(5.5)</td><td></td><td></td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>135.2</td><td>27.7</td><td>41.1</td><td>11.6</td><td>9.1</td><td>1.0</td><td>3.4</td><td>0.6</td><td></td><td></td><td></td><td></td></tr><tr><td>Prior Service Cost/(Credit)</td><td>4.5</td><td>1.5</td><td>0.6</td><td>0.5</td><td>(21.6)</td><td>1.1</td><td>(17.0)</td><td>0.6</td><td></td><td></td><td></td><td></td></tr><tr><td>Total Net Periodic Benefit Expense/(Income)</td><td>$   64.9</td><td>$   17.6</td><td>$   12.3</td><td>$   3.0</td><td>$    (39.6)</td><td>$    (0.4)</td><td>$    (31.8)</td><td>$    —</td><td></td><td></td><td></td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$   9.8</td><td>$   9.1</td><td>$   3.3</td><td>N/A</td><td>$    (0.7)</td><td>$    (1.1)</td><td>$    (0.5)</td><td></td><td></td><td></td><td></td></tr></table>

The following actuarial assumptions were used to calculate Pension, SERP and PBOP expense amounts:

<table><tr><td rowspan="2"></td><td colspan="3">Pension and SERP</td><td colspan="3">PBOP</td></tr><tr><td colspan="3">For the Years Ended December 31,</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td></td><td>2019</td><td>2018</td><td>2017</td><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>Discount Rate</td><td>2.63% - 3.55%</td><td>3.85% - 4.62%</td><td>3.20% - 3.90%</td><td>3.85% - 4.65%</td><td>3.28% - 3.94%</td><td>3.48% - 4.64%</td></tr><tr><td>Expected Long-Term Rate of Return</td><td>8.25%</td><td>8.25%</td><td>8.25%</td><td>8.25%</td><td></td><td>8.25%</td></tr><tr><td>Compensation/Progression Rate</td><td>3.50% - 4.00%</td><td>3.50% - 4.00%</td><td>3.50%</td><td>N/A</td><td>N/A</td><td>N/A</td></tr></table>

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:



<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="4">Pension and SERP</td><td colspan="4">PBOP</td></tr><tr><td colspan="2">Regulatory Assets</td><td colspan="2">OCI</td><td colspan="2">Regulatory Assets</td><td colspan="2">OCI</td></tr><tr><td colspan="4">For the Years Ended December 31,</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td></td><td>2019</td><td>2018</td><td>2019</td><td>2018</td><td>2019</td><td>2018</td><td>2017</td><td>2018</td></tr><tr><td>Actuarial Losses/(Gains) Arising During the Year</td><td>$ 591.6</td><td>$ 48.6</td><td>$ 15.4</td><td>$ 0.7</td><td>$ 4.6</td><td>$ 6.4</td><td>$ 2.3</td><td>$ (1.2)</td></tr><tr><td>Actuarial Losses Reclassified as Net Periodic Benefit Expense</td><td>(137.8)</td><td>(140.1)</td><td>(5.4)</td><td>(5.6)</td><td>(8.0)</td><td>(9.9)</td><td>(0.3)</td><td>(0.4)</td></tr><tr><td>Actuarial Losses Securitized as Stranded Costs (1)</td><td>—</td><td>(36.7)</td><td>—</td><td>—</td><td>—</td><td>(0.8)</td><td>—</td><td>—</td></tr><tr><td>Prior Service Cost Arising During the Year</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>1.3</td><td>—</td><td>—</td></tr><tr><td>Prior Service (Cost)/Credit Reclassified as Net Periodic Benefit (Expense)/Income</td><td>(0.7)</td><td>(3.9)</td><td>(0.2)</td><td>(0.4)</td><td>25.1</td><td>23.6</td><td>(1.6)</td><td>—</td></tr><tr><td>Prior Service Cost Securitized as Stranded Costs (1)</td><td>—</td><td>(0.1)</td><td>—</td><td>—</td><td>—</td><td>(1.3)</td><td>—</td><td>—</td></tr></table>

(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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="2">Regulatory Assets as of December 31,</td><td rowspan="2">Expected 2020 Expense/(Income)</td><td colspan="2">OCI as of December 31,</td><td rowspan="2">Expected 2020 Expense</td></tr><tr><td>2019</td><td>2018</td><td>2019</td><td>2018</td></tr><tr><td>Pension and SERP</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>$ 2,261.4</td><td>$ 1,807.6</td><td>$ 190.3</td><td>$ 90.8</td><td>$ 80.8</td><td>$ 7.2</td></tr><tr><td>Prior Service Cost</td><td>5.6</td><td>6.3</td><td>0.9</td><td>0.9</td><td>1.1</td><td>0.2</td></tr><tr><td>PBOP</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>$ 203.9</td><td>$ 207.3</td><td>$ 8.3</td><td>$ 7.0</td><td>$ 5.0</td><td>$ 0.2</td></tr><tr><td>Prior Service (Credit)/Cost</td><td>(172.5)</td><td>(197.6)</td><td>(21.4)</td><td>1.0</td><td>2.6</td><td>0.2</td></tr></table>

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:

<table><tr><td>(Millions of Dollars)</td><td>2020</td><td>2021</td><td>2022</td><td>2023</td><td>2024</td><td>2025 - 2029</td></tr><tr><td>Pension and SERP</td><td>$ 320.1</td><td>$ 328.7</td><td>$ 337.5</td><td>$ 346.5</td><td>$ 352.4</td><td>$ 1,813.1</td></tr><tr><td>PBOP</td><td>58.1</td><td>57.9</td><td>57.3</td><td>56.8</td><td>56.2</td><td>264.7</td></tr></table>

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,

<table><tr><td rowspan="3"></td><td colspan="2">2019</td><td colspan="2">2018</td></tr><tr><td colspan="2">Eversource Pension Plan and Tax-Exempt Assets Within PBOP Plan</td><td colspan="2">Eversource Pension Plan and Tax-Exempt Assets Within PBOP Plans</td></tr><tr><td>Target Asset Allocation</td><td>Assumed Rate of Return</td><td>Target Asset Allocation</td><td>Assumed Rate of Return</td></tr><tr><td>Equity Securities:</td><td></td><td></td><td></td><td></td></tr><tr><td>United States</td><td>15.0%</td><td>8.5%</td><td>15.0%</td><td>8.5%</td></tr><tr><td>Global</td><td>10.0%</td><td>8.75%</td><td>10.0%</td><td>8.75%</td></tr><tr><td>Non-United States</td><td>8.0%</td><td>8.5%</td><td>8.0%</td><td>8.5%</td></tr><tr><td>Emerging Markets</td><td>4.0%</td><td>10.0%</td><td>4.0%</td><td>10.0%</td></tr><tr><td>Debt Securities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Fixed Income</td><td>13.0%</td><td>4.0%</td><td>13.0%</td><td>4.0%</td></tr><tr><td>Public High Yield Fixed Income</td><td>4.0%</td><td>6.5%</td><td>4.0%</td><td>6.5%</td></tr><tr><td>Private Debt</td><td>15.0%</td><td>9.0%</td><td>15.0%</td><td>9.0%</td></tr><tr><td>Private Equity</td><td>15.0%</td><td>12.0%</td><td>15.0%</td><td>12.0%</td></tr><tr><td>Real Assets</td><td>16.0%</td><td>7.5%</td><td>16.0%</td><td>7.5%</td></tr></table>

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

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="11">Fair Value Measurements as of December 31,</td></tr><tr><td colspan="6">2019</td><td colspan="5">2018</td></tr><tr><td>Level 1</td><td>Level 2</td><td>Uncategorized</td><td>Total</td><td>Level 1</td><td>Level 2</td><td>Uncategorized</td><td>Total</td><td></td><td></td><td></td></tr><tr><td>Asset Category:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Equity Securities (1)</td><td>$ 592.6</td><td>$ —</td><td>$ 1,349.9</td><td>$ 1,942.5</td><td>$ 443.4</td><td>$ —</td><td>$ 1,377.8</td><td>$ 1,821.2</td><td></td><td></td><td></td></tr><tr><td>Fixed Income (2)</td><td>99.4</td><td>303.0</td><td>1,222.8</td><td>1,625.2</td><td>85.5</td><td>160.8</td><td>1,265.5</td><td>1,511.8</td><td></td><td></td><td></td></tr><tr><td>Private Equity</td><td>16.9</td><td>—</td><td>971.4</td><td>988.3</td><td>6.1</td><td>—</td><td>834.0</td><td>840.1</td><td></td><td></td><td></td></tr><tr><td>Real Assets (3)</td><td>58.7</td><td>—</td><td>615.0</td><td>673.7</td><td>62.9</td><td>—</td><td>569.1</td><td>632.0</td><td></td><td></td><td></td></tr><tr><td>Total</td><td>$ 767.6</td><td>$ 303.0</td><td>$ 4,159.1</td><td>$ 5,229.7</td><td>$ 597.9</td><td>$ 160.8</td><td>$ 4,046.4</td><td>$ 4,805.1</td><td></td><td></td><td></td></tr><tr><td>Less: 401(h) PBOP Assets (4)</td><td></td><td></td><td></td><td>(261.1)</td><td></td><td></td><td></td><td></td><td></td><td></td><td>(231.2)</td></tr><tr><td>Total Pension Assets</td><td></td><td></td><td></td><td>$ 4,968.6</td><td></td><td></td><td></td><td></td><td>$ 4,573.9</td><td></td><td></td></tr></table>

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="11">PBOP Plan</td></tr><tr><td colspan="6">Fair Value Measurements as of December 31,</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td colspan="3">Level 1</td><td colspan="2">Level 2</td><td colspan="2">Uncategorized</td><td>Total</td><td>Level 1</td><td>Level 2</td><td>Uncategorized</td><td>Total</td></tr><tr><td>Asset Category:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Equity Securities (1)</td><td>$</td><td>158.0</td><td>$</td><td>—</td><td>$</td><td>187.0</td><td>$</td><td>345.0</td><td>$</td><td>—</td><td>$</td><td>210.5</td></tr><tr><td>Fixed Income (2)</td><td></td><td>15.8</td><td></td><td>39.6</td><td></td><td>148.1</td><td></td><td>203.5</td><td></td><td>22.0</td><td></td><td>40.3</td></tr><tr><td>Private Equity</td><td></td><td>—</td><td></td><td>—</td><td></td><td>26.5</td><td></td><td>26.5</td><td></td><td>—</td><td></td><td>32.7</td></tr><tr><td>Real Assets (3)</td><td></td><td>51.2</td><td></td><td>—</td><td></td><td>48.6</td><td></td><td>99.8</td><td></td><td>27.5</td><td></td><td>70.5</td></tr><tr><td>Total</td><td>$</td><td>225.0</td><td>$</td><td>39.6</td><td>$</td><td>410.2</td><td>$</td><td>674.8</td><td>$</td><td>141.4</td><td>$</td><td>436.7</td></tr><tr><td>Add: 401(h) PBOP Assets (4)</td><td></td><td></td><td></td><td></td><td></td><td>261.1</td><td></td><td></td><td></td><td></td><td></td><td>231.2</td></tr><tr><td>Total PBOP Assets</td><td></td><td></td><td></td><td></td><td></td><td>$</td><td>935.9</td><td></td><td></td><td></td><td></td><td>$</td></tr></table>

(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.

## 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:

<table><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>2019</td><td>$ 41.6</td><td>$ 5.5</td><td>$ 10.3</td><td>$ 3.5</td></tr><tr><td>2018</td><td>38.4</td><td>5.0</td><td>9.7</td><td>3.3</td></tr><tr><td>2017</td><td>34.5</td><td>4.6</td><td>8.5</td><td>3.7</td></tr></table>

## 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:

<table><tr><td></td><td>RSUs (Units)</td><td>Weighted Average Grant-Date Fair Value</td></tr><tr><td>Outstanding as of December 31, 2018</td><td>782,365</td><td>50.25</td></tr><tr><td>Granted</td><td>271,144</td><td>67.91</td></tr><tr><td>Shares Issued</td><td>(263,219)</td><td>55.34</td></tr><tr><td>Forfeited</td><td>(16,127)</td><td>63.31</td></tr><tr><td>Outstanding as of December 31, 2019</td><td>774,163</td><td>54.43</td></tr></table>



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:

<table><tr><td></td><td>Performance Shares (Units)</td><td>Weighted Average Grant-Date Fair Value</td></tr><tr><td>Outstanding as of December 31, 2018</td><td>499,564</td><td>56.08</td></tr><tr><td>Granted</td><td>165,022</td><td>68.33</td></tr><tr><td>Shares Issued</td><td>(162,959)</td><td>55.69</td></tr><tr><td>Forfeited</td><td>(14,720)</td><td>58.20</td></tr><tr><td>Outstanding as of December 31, 2019</td><td>486,907</td><td>60.30</td></tr></table>

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:

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td></tr><tr><td>Compensation Expense</td><td>$ 27.3</td><td>$ 21.4</td><td>$ 19.7</td><td></td></tr><tr><td>Future Income Tax Benefit</td><td>7.0</td><td>5.4</td><td>8.0</td><td></td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">2019</td><td colspan="4">2018</td><td colspan="4">2017</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&ampamp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td><td></td><td></td></tr><tr><td>Compensation Expense</td><td>$ 9.8</td><td>$ 9.7</td><td>$ 3.3</td><td>$ 7.8</td><td>$ 7.7</td><td>$ 2.9</td><td>$ 7.0</td><td>$ 7.0</td><td>$ 3.2</td><td></td><td></td><td></td></tr><tr><td>Future Income Tax Benefit</td><td>2.5</td><td>2.5</td><td>0.8</td><td>2.0</td><td>1.9</td><td>0.7</td><td>2.9</td><td>2.8</td><td>1.3</td><td></td><td></td><td></td></tr></table>

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:

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="4">As of and For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td></tr><tr><td>Actuarially-Determined Liability</td><td>$ 52.0</td><td>$ 49.1</td><td>$ 53.4</td><td></td></tr><tr><td>Other Retirement Benefits Expense</td><td>2.7</td><td>2.7</td><td>2.8</td><td></td></tr></table>



As of and For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="4">2019</td><td colspan="4">2018</td><td colspan="4">2017</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&ampamp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&ampamp;P</td><td>PSNH</td><td></td></tr><tr><td>Actuarially-Determined Liability</td><td>$ 0.2</td><td>$ 0.1</td><td>$ 1.7</td><td>$ 0.3</td><td>$ 0.1</td><td>$ 1.7</td><td>$ 0.3</td><td>$ 0.1</td><td>$ 1.7</td><td>$ 0.3</td><td>$ 0.1</td><td>$ 1.9</td></tr><tr><td>Other Retirement Benefits Expense</td><td>1.0</td><td>0.9</td><td>0.4</td><td>1.1</td><td>1.1</td><td>0.4</td><td>1.0</td><td>1.0</td><td>0.5</td><td></td><td></td><td></td></tr></table>

## 12. INCOME TAXES

The components of income tax expense are as follows:

For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>Current Income Taxes:</td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>$ 56.9</td><td>$ 106.5</td><td>$ 58.9</td></tr><tr><td>State</td><td>10.5</td><td>10.6</td><td>31.6</td></tr><tr><td>Total Current</td><td>67.4</td><td>117.1</td><td>90.5</td></tr><tr><td>Deferred Income Taxes, Net:</td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>138.4</td><td>122.6</td><td>433.0</td></tr><tr><td>State</td><td>71.4</td><td>52.2</td><td>58.6</td></tr><tr><td>Total Deferred</td><td>209.8</td><td>174.8</td><td>491.6</td></tr><tr><td>Investment Tax Credits, Net</td><td>(3.7)</td><td>(2.9)</td><td>(3.2)</td></tr><tr><td>Income Tax Expense</td><td>$ 273.5</td><td>$ 289.0</td><td>$ 578.9</td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="4">2019</td><td colspan="4">2018</td><td colspan="4">2017</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&ampamp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td><td></td><td></td></tr><tr><td>Current Income Taxes:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>$ 68.4</td><td>$ 82.6</td><td>$ 22.9</td><td>$ 54.2</td><td>$ 79.3</td><td>$ 12.2</td><td>$ 50.9</td><td>$ 107.8</td><td>$ 18.6</td><td></td><td></td><td></td></tr><tr><td>State</td><td>15.4</td><td>18.2</td><td>2.2</td><td>20.9</td><td>30.0</td><td>(0.5)</td><td>17.4</td><td>25.6</td><td>6.2</td><td></td><td></td><td></td></tr><tr><td>Total Current</td><td>83.8</td><td>100.8</td><td>25.1</td><td>75.1</td><td>109.3</td><td>11.7</td><td>68.3</td><td>133.4</td><td>24.8</td><td></td><td></td><td></td></tr><tr><td>Deferred Income Taxes, Net:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>35.2</td><td>0.1</td><td>5.8</td><td>48.5</td><td>27.9</td><td>15.4</td><td>123.9</td><td>88.1</td><td>52.7</td><td></td><td></td><td></td></tr><tr><td>State</td><td>18.8</td><td>27.0</td><td>10.1</td><td>6.4</td><td>13.5</td><td>20.5</td><td>(4.6)</td><td>22.4</td><td>11.2</td><td></td><td></td><td></td></tr><tr><td>Total Deferred</td><td>54.0</td><td>27.1</td><td>15.9</td><td>54.9</td><td>41.4</td><td>35.9</td><td>119.3</td><td>110.5</td><td>63.9</td><td></td><td></td><td></td></tr><tr><td>Investment Tax Credits, Net</td><td>(0.8)</td><td>(2.6)</td><td>—</td><td>(0.9)</td><td>(1.8)</td><td>—</td><td>(1.0)</td><td>(1.8)</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Income Tax Expense</td><td>$ 137.0</td><td>$ 125.3</td><td>$ 41.0</td><td>$ 129.1</td><td>$ 148.9</td><td>$ 47.6</td><td>$ 186.6</td><td>$ 242.1</td><td>$ 88.7</td><td></td><td></td><td></td></tr></table>

A reconciliation between income tax expense and the expected tax expense at the statutory rate is as follows:

For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="4">2019</td><td colspan="4">2018</td><td colspan="4">2017</td></tr><tr><td>Income Before Income Tax Expense</td><td>$</td><td>1,190.1</td><td>$</td><td>1,329.5</td><td>$</td><td>1,574.4</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017</td><td></td><td>249.9</td><td></td><td>279.2</td><td></td><td></td><td>551.0</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Tax Effect of Differences:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Depreciation</td><td></td><td>1.9</td><td></td><td>(30.8)</td><td></td><td></td><td>(10.8)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Investment Tax Credit Amortization</td><td></td><td>(3.7)</td><td></td><td>(2.9)</td><td></td><td></td><td>(3.2)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>State Income Taxes, Net of Federal Impact</td><td></td><td>24.6</td><td></td><td>44.4</td><td></td><td></td><td>47.7</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Dividends on ESOP</td><td></td><td>(5.1)</td><td></td><td>(5.1)</td><td></td><td></td><td>(8.4)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Tax Asset Valuation Allowance/Reserve Adjustments</td><td></td><td>40.1</td><td></td><td>5.2</td><td></td><td></td><td>7.0</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Excess Stock Benefit</td><td></td><td>(1.5)</td><td></td><td>(1.5)</td><td></td><td></td><td>(2.9)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>EDIT Amortization</td><td></td><td>(37.4)</td><td></td><td>(5.0)</td><td></td><td></td><td>—</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Other, Net</td><td></td><td>4.7</td><td></td><td>5.5</td><td></td><td></td><td>(1.5)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Income Tax Expense</td><td></td><td>$ 273.5</td><td>$</td><td>289.0</td><td>$</td><td>578.9</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Effective Tax Rate</td><td></td><td>23.0%</td><td></td><td>21.7%</td><td></td><td>36.8%</td><td></td><td></td><td></td><td></td><td></td><td></td></tr></table>



For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars, except percentages)</td><td colspan="4">2019</td><td colspan="4">2018</td><td colspan="4">2017</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp; P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Income Before Income Tax Expense</td><td>$ 547.8</td><td>$ 557.3</td><td>$ 175.0</td><td>$ 506.8</td><td>$ 532.0</td><td>$ 163.5</td><td>$ 563.4</td><td>$ 616.8</td><td>$ 224.7</td><td></td><td></td><td></td></tr><tr><td>Statutory Federal Income Tax Expense at 21% in 2019 and 2018, and 35% in 2017</td><td>115.0</td><td>117.0</td><td>36.8</td><td>106.4</td><td>111.7</td><td>34.3</td><td>197.2</td><td>215.9</td><td>78.6</td><td></td><td></td><td></td></tr><tr><td>Tax Effect of Differences:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Depreciation</td><td>(0.2)</td><td>(3.0)</td><td>(0.8)</td><td>(1.2)</td><td>(2.8)</td><td>0.1</td><td>(5.2)</td><td>(3.0)</td><td>1.1</td><td></td><td></td><td></td></tr><tr><td>Investment Tax Credit Amortization</td><td>(0.8)</td><td>(2.6)</td><td>—</td><td>(0.9)</td><td>(1.8)</td><td>—</td><td>(1.0)</td><td>(1.8)</td><td>—</td><td></td><td></td><td></td></tr><tr><td>State Income Taxes, Net of Federal Impact</td><td>2.5</td><td>35.7</td><td>9.8</td><td>14.5</td><td>33.2</td><td>15.8</td><td>4.5</td><td>31.2</td><td>11.3</td><td></td><td></td><td></td></tr><tr><td>Tax Asset Valuation Allowance/Reserve Adjustments</td><td>24.5</td><td>—</td><td>—</td><td>7.1</td><td>1.2</td><td>—</td><td>(9.5)</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Excess Stock Benefit</td><td>(0.5)</td><td>(0.5)</td><td>(0.2)</td><td>(0.1)</td><td>(0.1)</td><td>(0.1)</td><td>(0,7)</td><td>(0.7)</td><td>(0.3)</td><td></td><td></td><td></td></tr><tr><td>EDIT Amortization</td><td>(5.8)</td><td>(22.9)</td><td>(4.0)</td><td>—</td><td>—</td><td>(4.4)</td><td>—</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Other, Net</td><td>2.3</td><td>1.6</td><td>(0.6)</td><td>3.3</td><td>7.5</td><td>1.9</td><td>1.3</td><td>0.5</td><td>(2.0)</td><td></td><td></td><td></td></tr><tr><td>Income Tax Expense</td><td>$ 137.0</td><td>$ 125.3</td><td>$ 41.0</td><td>$ 129.1</td><td>$ 148.9</td><td>$ 47.6</td><td>$ 186.6</td><td>$ 242.1</td><td>$ 88.7</td><td></td><td></td><td></td></tr><tr><td>Effective Tax Rate</td><td>25.0%</td><td>22.5%</td><td>23.4%</td><td>25.5%</td><td>28.0%</td><td>29.1%</td><td>33.1%</td><td>39.2%</td><td>39.5%</td><td></td><td></td><td></td></tr></table>

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:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="12">As of December 31,</td></tr><tr><td colspan="6">2019</td><td colspan="6">2018</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSN</td><td></td><td></td><td></td><td></td></tr><tr><td>Deferred Tax Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Employee Benefits</td><td>$ 509.4</td><td>$ 125.4</td><td>$ 54.8</td><td>$ 46.7</td><td>$ 388.2</td><td>$ 94.5</td><td>$ 35.0</td><td>$ 31.1</td><td></td><td></td><td></td><td></td></tr><tr><td>Derivative Liabilities</td><td>105.0</td><td>103.6</td><td>—</td><td>—</td><td>111.4</td><td>111.4</td><td>—</td><td>—</td><td></td><td></td><td></td><td></td></tr><tr><td>Regulatory Deferrals - Liabilities</td><td>267.0</td><td>37.1</td><td>165.7</td><td>19.0</td><td>299.3</td><td>38.6</td><td>195.5</td><td>16.1</td><td></td><td></td><td></td><td></td></tr><tr><td>Allowance for Uncollectible Accounts</td><td>56.7</td><td>25.7</td><td>17.7</td><td>2.8</td><td>54.0</td><td>23.1</td><td>17.8</td><td>3.0</td><td></td><td></td><td></td><td></td></tr><tr><td>Tax Effect - Tax Regulatory Liabilities</td><td>830.4</td><td>333.5</td><td>280.9</td><td>111.3</td><td>830.3</td><td>336.8</td><td>288.9</td><td>111.7</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Operating Loss Carryforwards</td><td>9.1</td><td>—</td><td>—</td><td>—</td><td>28.5</td><td>—</td><td>—</td><td>0.6</td><td></td><td></td><td></td><td></td></tr><tr><td>Purchase Accounting Adjustment</td><td>58.7</td><td>—</td><td>—</td><td>—</td><td>64.2</td><td>—</td><td>—</td><td>—</td><td></td><td></td><td></td><td></td></tr><tr><td>Other</td><td>190.4</td><td>92.0</td><td>35.8</td><td>20.0</td><td>166.2</td><td>81.1</td><td>15.6</td><td>33.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Total Deferred Tax Assets</td><td>2,026.7</td><td>717.3</td><td>554.9</td><td>199.8</td><td>1,942.1</td><td>685.5</td><td>552.8</td><td>195.9</td><td></td><td></td><td></td><td></td></tr><tr><td>Less: Valuation Allowance</td><td>43.0</td><td>24.9</td><td>—</td><td>—</td><td>19.5</td><td>10.7</td><td>—</td><td>—</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Deferred Tax Assets</td><td>$ 1,983.7</td><td>$ 692.4</td><td>$ 554.9</td><td>$ 199.8</td><td>$ 1,922.6</td><td>$ 674.8</td><td>$ 552.8</td><td>$ 195.9</td><td></td><td></td><td></td><td></td></tr><tr><td>Deferred Tax Liabilities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Accelerated Depreciation and Other Plant-Related Differences</td><td>$ 3,901.0</td><td>$ 1,362.2</td><td>$ 1,391.9</td><td>$ 428.9</td><td>$ 3,724.2</td><td>$ 1,293.3</td><td>$ 1,342.4</td><td>$ 410.6</td><td></td><td></td><td></td><td></td></tr><tr><td>Property Tax Accruals</td><td>76.8</td><td>36.8</td><td>29.0</td><td>4.7</td><td>73.2</td><td>35.4</td><td>26.3</td><td>5.2</td><td></td><td></td><td></td><td></td></tr><tr><td>Regulatory Amounts:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Regulatory Deferrals - Assets</td><td>1,155.6</td><td>340.7</td><td>276.2</td><td>260.9</td><td>1,025.9</td><td>320.1</td><td>277.4</td><td>213.8</td><td></td><td></td><td></td><td></td></tr><tr><td>Tax Effect - Tax Regulatory Assets</td><td>238.2</td><td>171.7</td><td>11.7</td><td>8.3</td><td>238.9</td><td>167.0</td><td>9.7</td><td>8.1</td><td></td><td></td><td></td><td></td></tr><tr><td>Goodwill Regulatory Asset - 1999 Merger</td><td>90.6</td><td>—</td><td>77.8</td><td>—</td><td>95.2</td><td>—</td><td>81.7</td><td>—</td><td></td><td></td><td></td><td></td></tr><tr><td>Derivative Assets</td><td>19.7</td><td>19.7</td><td>—</td><td>—</td><td>20.1</td><td>19.9</td><td>—</td><td>—</td><td></td><td></td><td></td><td></td></tr><tr><td>Other</td><td>257.6</td><td>5.9</td><td>125.6</td><td>3.2</td><td>251.1</td><td>5.9</td><td>109.8</td><td>39.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Total Deferred Tax Liabilities</td><td>$ 5,739.5</td><td>$ 1,937.0</td><td>$ 1,912.2</td><td>$ 706.0</td><td>$ 5,428.6</td><td>$ 1,841.6</td><td>$ 1,847.3</td><td>$ 677.1</td><td></td><td></td><td></td><td></td></tr></table>



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,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">2019</td><td colspan="5">2018</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Expiration Range</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSN</td><td>Expiration Range</td></tr><tr><td>Federal Net Operating Loss</td><td>$ 19.8</td><td>$ —</td><td>$ —</td><td>$ —</td><td>2033 - 2037</td><td>$ 103.6</td><td>$ —</td><td>$ —</td><td>$ —</td><td>2033 - 203</td></tr><tr><td>Federal Charitable Contribution</td><td>—</td><td>—</td><td>—</td><td>—</td><td>2020 - 2022</td><td>2.2</td><td>—</td><td>—</td><td>—</td><td>2020 - 2022</td></tr><tr><td>State Net Operating Loss</td><td>65.5</td><td>—</td><td>—</td><td>—</td><td>2020 - 2038</td><td>80.7</td><td>—</td><td>—</td><td>—</td><td>2019 - 2038</td></tr><tr><td>State Tax Credit</td><td>168.1</td><td>122.3</td><td>—</td><td>—</td><td>2019 - 2024</td><td>148.9</td><td>107.0</td><td>—</td><td>—</td><td>2018 - 2023</td></tr><tr><td>State Charitable Contribution</td><td>9.9</td><td>—</td><td>—</td><td>—</td><td>2019 - 2023</td><td>9.6</td><td>—</td><td>—</td><td>—</td><td>2019 - 2023</td></tr></table>

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:

<table><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td></tr><tr><td>Balance as of January 1, 2017</td><td>$ 48.4</td><td>$ 15.3</td></tr><tr><td>Gross Increases - Current Year</td><td>11.4</td><td>4.7</td></tr><tr><td>Gross Decreases - Prior Year</td><td>(0.9)</td><td>(0.5)</td></tr><tr><td>Lapse of Statute of Limitations</td><td>(7.2)</td><td>(1.4)</td></tr><tr><td>Balance as of December 31, 2017</td><td>51.7</td><td>18.1</td></tr><tr><td>Gross Increases - Current Year</td><td>9.2</td><td>3.2</td></tr><tr><td>Gross Decreases - Prior Year</td><td>(6.5)</td><td>(0.9)</td></tr><tr><td>Lapse of Statute of Limitations</td><td>(8.5)</td><td>(2.2)</td></tr><tr><td>Balance as of December 31, 2018</td><td>45.9</td><td>18.2</td></tr><tr><td>Gross Increases - Current Year</td><td>12.1</td><td>4.0</td></tr><tr><td>Gross Increases - Prior Year</td><td>3.4</td><td>3.3</td></tr><tr><td>Lapse of Statute of Limitations</td><td>(6.4)</td><td>(2.4)</td></tr><tr><td>Balance as of December 31, 2019</td><td>$ 55.0</td><td>$ 23.1</td></tr></table>

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:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="4">Other Interest Expense/(Income)</td><td colspan="4">Accrued Interest Expense</td></tr><tr><td colspan="4">For the Years Ended December 31,</td><td colspan="4">As of December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td><td>2019</td><td>2018</td><td></td><td></td></tr><tr><td>Eversource</td><td>$ —</td><td>$ —</td><td>(1.7)</td><td>$ —</td><td>$ 0.1</td><td>$ 0.1</td><td></td><td></td></tr></table>



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:

<table><tr><td>Description</td><td>Tax Years</td></tr><tr><td>Federal</td><td>2019</td></tr><tr><td>Connecticut</td><td>2016 - 2019</td></tr><tr><td>Massachusetts</td><td>2016 - 2019</td></tr><tr><td>New Hampshire</td><td>2017 - 2019</td></tr></table>

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:

<table><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Balance as of January 1, 2018</td><td>$ 54.9</td><td>$ 4.7</td><td>$ 2.7</td><td>$ 5.7</td></tr><tr><td>Additions</td><td>23.5</td><td>1.9</td><td>9.7</td><td>—</td></tr><tr><td>Payments/Reductions</td><td>(13.7)</td><td>(1.2)</td><td>(1.5)</td><td>(0.3)</td></tr><tr><td>Balance as of December 31, 2018</td><td>64.7</td><td>5.4</td><td>10.9</td><td>5.4</td></tr><tr><td>Additions</td><td>26.5</td><td>7.0</td><td>0.5</td><td>2.8</td></tr><tr><td>Payments/Reductions</td><td>(10.2)</td><td>(1.0)</td><td>(3.4)</td><td>(0.7)</td></tr><tr><td>Balance as of December 31, 2019</td><td>$ 81.0</td><td>$ 11.4</td><td>$ 8.0</td><td>$ 7.5</td></tr></table>

The number of environmental sites for which remediation or long-term monitoring, preliminary site work or site assessment is being performed are as follows:

<table><tr><td></td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>2019</td><td>57</td><td>15</td><td>15</td><td>9</td></tr><tr><td>2018</td><td>60</td><td>15</td><td>16</td><td>9</td></tr></table>

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.

## 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:

<table><tr><td colspan="10">Eversource</td></tr><tr><td>(Millions of Dollars)</td><td>2020</td><td>2021</td><td>2022</td><td>2023</td><td>2024</td><td>Thereafter</td><td>Total</td><td></td><td></td></tr><tr><td>Renewable Energy</td><td>$ 614.6</td><td>$ 594.3</td><td>$ 651.7</td><td>$ 629.1</td><td>$ 624.8</td><td>$ 3,590.6</td><td>$ 6,705.1</td><td></td><td></td></tr><tr><td>Purchased Power and Capacity</td><td>73.5</td><td>69.0</td><td>75.1</td><td>81.6</td><td>75.9</td><td>71.5</td><td>446.6</td><td></td><td></td></tr><tr><td>Speaker CFDs</td><td>22.4</td><td>23.0</td><td>16.9</td><td>20.1</td><td>15.5</td><td>29.8</td><td>127.7</td><td></td><td></td></tr><tr><td>Natural Gas Procurement</td><td>266.2</td><td>255.3</td><td>202.8</td><td>166.7</td><td>165.7</td><td>1,093.3</td><td>2,150.0</td><td></td><td></td></tr><tr><td>Transmission Support Commitments</td><td>22.1</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>22.1</td><td></td><td></td></tr><tr><td>Total</td><td>$ 998.8</td><td>$ 941.6</td><td>$ 946.5</td><td>$ 897.5</td><td>$ 881.9</td><td>$ 4,785.2</td><td>$ 9,451.5</td><td></td><td></td></tr></table>

<table><tr><td colspan="9">CL&amp;P</td></tr><tr><td>(Millions of Dollars)</td><td>2020</td><td>2021</td><td>2022</td><td>2023</td><td>2024</td><td>Thereafter</td><td>Total</td><td></td></tr><tr><td>Renewable Energy</td><td>$ 457.3</td><td>$ 459.6</td><td>$ 514.4</td><td>$ 516.2</td><td>$ 517.4</td><td>$ 2,790.6</td><td>$ 5,255.5</td><td></td></tr><tr><td>Purchased Power and Capacity</td><td>69.8</td><td>65.3</td><td>71.4</td><td>78.0</td><td>72.9</td><td>55.5</td><td>412.9</td><td></td></tr><tr><td>Speaker CFDs</td><td>22.4</td><td>23.0</td><td>16.9</td><td>20.1</td><td>15.5</td><td>29.8</td><td>127.7</td><td></td></tr><tr><td>Transmission Support Commitments</td><td>8.7</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>8.7</td><td></td></tr><tr><td>Total</td><td>$ 558.2</td><td>$ 547.9</td><td>$ 602.7</td><td>$ 614.3</td><td>$ 605.8</td><td>$ 2,875.9</td><td>$ 5,804.8</td><td></td></tr></table>

<table><tr><td colspan="9">NSTAR Electric</td></tr><tr><td>(Millions of Dollars)</td><td>2020</td><td>2021</td><td>2022</td><td>2023</td><td>2024</td><td>Thereafter</td><td>Total</td><td></td></tr><tr><td>Renewable Energy</td><td>$ 95.5</td><td>$ 91.2</td><td>$ 91.4</td><td>$ 66.6</td><td>$ 63.8</td><td>$ 418.1</td><td>$ 826.6</td><td></td></tr><tr><td>Purchased Power and Capacity</td><td>3.1</td><td>3.1</td><td>3.1</td><td>3.0</td><td>3.0</td><td>16.0</td><td>31.3</td><td></td></tr><tr><td>Transmission Support Commitments</td><td>8.7</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>8.7</td><td></td></tr><tr><td>Total</td><td>$ 107.3</td><td>$ 94.3</td><td>$ 94.5</td><td>$ 69.6</td><td>$ 66.8</td><td>$ 434.1</td><td>$ 866.6</td><td></td></tr></table>

<table><tr><td colspan="9">PSNH</td></tr><tr><td>(Millions of Dollars)</td><td>2020</td><td>2021</td><td>2022</td><td>2023</td><td>2024</td><td>Thereafter</td><td>Total</td><td></td></tr><tr><td>Renewable Energy</td><td>$ 61.8</td><td>$ 43.5</td><td>$ 45.9</td><td>$ 46.3</td><td>$ 43.6</td><td>$ 381.9</td><td>$ 623.0</td><td></td></tr><tr><td>Purchased Power and Capacity</td><td>0.6</td><td>0.6</td><td>0.6</td><td>0.6</td><td>—</td><td>—</td><td>2.4</td><td></td></tr><tr><td>Transmission Support Commitments</td><td>4.7</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>4.7</td><td></td></tr><tr><td>Total</td><td>$ 67.1</td><td>$ 44.1</td><td>$ 46.5</td><td>$ 46.9</td><td>$ 43.6</td><td>$ 381.9</td><td>$ 630.1</td><td></td></tr></table>

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:

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>Renewable Energy</td><td>$ 320.8</td><td>$ 218.5</td><td>$ 235.5</td></tr><tr><td>Purchased Power and Capacity</td><td>62.1</td><td>72.0</td><td>103.9</td></tr><tr><td>Peaker CfDs</td><td>13.0</td><td>20.9</td><td>38.7</td></tr><tr><td>Natural Gas Procurement</td><td>448.5</td><td>432.4</td><td>377.0</td></tr><tr><td>Transmission Support Commitments</td><td>21.8</td><td>23.4</td><td>19.8</td></tr><tr><td>Coal, Wood and Other \( ^{(1)} \)</td><td>—</td><td>—</td><td>47.7</td></tr></table>



For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">2019</td><td colspan="4">2018</td><td colspan="4">2017</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;&amp; P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Renewable Energy</td><td>$ 160.6</td><td>$ 89.9</td><td>$ 70.3</td><td>$ 63.2</td><td>$ 89.8</td><td>$ 65.5</td><td>$ 51.0</td><td>$ 123.7</td><td>$ 60.8</td><td></td><td></td><td></td></tr><tr><td>Purchased Power and Capacity</td><td>50.4</td><td>5.1</td><td>6.6</td><td>49.4</td><td>4.4</td><td>18.2</td><td>81.0</td><td>4.0</td><td>18.9</td><td></td><td></td><td></td></tr><tr><td>Peaker CfDs</td><td>13.0</td><td>—</td><td>—</td><td>20.9</td><td>—</td><td>—</td><td>38.7</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Transmission Support Commitments</td><td>8.6</td><td>8.6</td><td>4.6</td><td>9.2</td><td>9.2</td><td>5.0</td><td>7.8</td><td>7.8</td><td>4.2</td><td></td><td></td><td></td></tr><tr><td>Coal, Wood and Other (1)</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>−</td><td>47.7</td><td></td><td></td><td></td></tr></table>

(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:

<table><tr><td>Company</td><td>Description</td><td>Maximum Exposure (in millions)</td><td>Expiration Dates</td></tr><tr><td>Various</td><td>Surety Bonds (1)</td><td>$ 29.2</td><td>2020 - 2021</td></tr><tr><td>Rocky River Realty Company and Eversource Service</td><td>Lease Payments for Real Estate</td><td>6.5</td><td>2024</td></tr><tr><td>Bay State Wind LLC</td><td>Real Estate Purchase</td><td>2.5</td><td>2020</td></tr><tr><td>Sunrise Wind LLC</td><td>Offshore Wind (2)</td><td>2.2</td><td>—</td></tr></table>

(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 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.



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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">For the Year Ended December 31, 2019</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td></tr><tr><td>Financing Lease Cost:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Amortization of Right-of-use-Assets</td><td>$ 1.7</td><td>$ 0.7</td><td>$ 0.2</td><td>$ 0.1</td><td></td></tr><tr><td>Interest on Lease Liabilities</td><td>1.2</td><td>0.6</td><td>0.6</td><td>—</td><td></td></tr><tr><td>Total Finance Lease Cost</td><td>2.9</td><td>1.3</td><td>0.8</td><td>0.1</td><td></td></tr><tr><td>Operating Lease Cost</td><td>11.7</td><td>0.5</td><td>3.4</td><td>0.1</td><td></td></tr><tr><td>Variable Lease Cost</td><td>60.5</td><td>13.3</td><td>—</td><td>47.2</td><td></td></tr><tr><td>Total Lease Cost</td><td>$ 75.1</td><td>$ 15.1</td><td>$ 4.2</td><td>$ 47.4</td><td></td></tr></table>

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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">NSTAR</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td></td></tr><tr><td>2018</td><td>$ 10.8</td><td>$ 10.9</td><td>$ 11.8</td><td>$ 2.5</td><td></td></tr><tr><td>2017</td><td>10.5</td><td>11.7</td><td>11.3</td><td>3.3</td><td></td></tr></table>

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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td rowspan="2">Balance Sheet Classification</td><td colspan="5">As of December 31, 2019</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td></tr><tr><td>Operating Leases:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Lease Right-of-use-Assets, Net</td><td>Other Long-Term Assets</td><td>$ 49.9</td><td>$ 0.7</td><td>$ 24.2</td><td>$ 0.4</td><td></td></tr><tr><td>Operating Lease Liabilities</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Lease Liabilities - Current Portion</td><td>Other Current Liabilities</td><td>$ 8.6</td><td>$ 0.5</td><td>$ 0.7</td><td>$ 0.1</td><td></td></tr><tr><td>Operating Lease Liabilities - Long-Term</td><td>Other Long-Term Liabilities</td><td>41.3</td><td>0.2</td><td>23.5</td><td>0.3</td><td></td></tr><tr><td>Total Operating Lease Liabilities</td><td></td><td>$ 49.9</td><td>$ 0.7</td><td>$ 24.2</td><td>$ 0.4</td><td></td></tr><tr><td>Finance Leases:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Finance Lease Right-of-use-Assets, Net</td><td>Property, Plant and Equipment, Net</td><td>$ 8.2</td><td>$ 1.9</td><td>$ 3.3</td><td>$ 0.9</td><td></td></tr><tr><td>Finance Lease Liabilities</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Finance Lease Liabilities - Current Portion</td><td>Other Current Liabilities</td><td>$ 2.4</td><td>$ 1.6</td><td>$ —</td><td>$ 0.1</td><td></td></tr><tr><td>Finance Lease Liabilities - Long-Term</td><td>Other Long-Term Liabilities</td><td>8.1</td><td>1.4</td><td>4.4</td><td>0.8</td><td></td></tr><tr><td>Total Finance Lease Liabilities</td><td></td><td>$ 10.5</td><td>$ 3.0</td><td>$ 4.4</td><td>$ 0.9</td><td></td></tr></table>

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):

<table><tr><td></td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>As of December 31, 2019</td><td></td><td></td><td></td><td></td></tr><tr><td>Weighted-Average Remaining Lease Term (Years):</td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Leases</td><td>12</td><td>2</td><td>20</td><td>9</td></tr><tr><td>Finance Leases</td><td>12</td><td>2</td><td>22</td><td>9</td></tr><tr><td>Weighted-Average Discount Rate (Percentage):</td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Leases</td><td>3.9%</td><td>2.5%</td><td>4.1%</td><td>3.7%</td></tr><tr><td>Finance Leases</td><td>4.0%</td><td>10.5%</td><td>2.9%</td><td>3.5%</td></tr></table>

<table><tr><td></td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>For the Year Ended December 31, 2019</td><td></td><td></td><td></td><td></td></tr><tr><td>Cash Paid for Amounts Included in the Measurement of Lease Liabilities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Cash Flows from Operating Leases</td><td>$ 11.4</td><td>$ 0.4</td><td>$ 1.6</td><td>$ 0.1</td></tr><tr><td>Operating Cash Flows from Finance Leases</td><td>1.2</td><td>0.6</td><td>0.6</td><td>—</td></tr><tr><td>Financing Cash Flows from Finance Leases</td><td>2.6</td><td>1.4</td><td>—</td><td>0.1</td></tr><tr><td>Supplemental Non-Cash Information on Lease Liabilities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities</td><td>2.9</td><td>1.0</td><td>0.1</td><td>0.2</td></tr><tr><td>Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities</td><td>2.0</td><td>—</td><td>—</td><td>—</td></tr></table>

Future minimum lease payments, excluding variable costs, under long-term leases, as of December 31, 2019 are as follows:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">Operating Leases</td><td colspan="5">Finance Leases</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSN</td><td></td></tr><tr><td>Year Ending December 31,</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>2020</td><td>$ 10.2</td><td>$ 0.5</td><td>$ 1.8</td><td>$ 0.1</td><td>$ 3.4</td><td>$ 2.0</td><td>$ 0.6</td><td>$ 0.1</td><td></td></tr><tr><td>2021</td><td>9.0</td><td>0.2</td><td>1.6</td><td>0.1</td><td>2.9</td><td>1.5</td><td>0.6</td><td>0.1</td><td></td></tr><tr><td>2022</td><td>7.4</td><td>—</td><td>1.6</td><td>0.1</td><td>1.5</td><td>—</td><td>0.6</td><td>0.1</td><td></td></tr><tr><td>2023</td><td>4.9</td><td>—</td><td>1.6</td><td>—</td><td>0.8</td><td>—</td><td>0.6</td><td>0.1</td><td></td></tr><tr><td>2024</td><td>2.8</td><td>—</td><td>1.7</td><td>—</td><td>0.8</td><td>—</td><td>0.7</td><td>0.1</td><td></td></tr><tr><td>Thereafter</td><td>28.9</td><td>0.1</td><td>28.7</td><td>0.2</td><td>13.1</td><td>—</td><td>12.6</td><td>0.5</td><td></td></tr><tr><td>Future lease payments</td><td>63.2</td><td>0.8</td><td>37.0</td><td>0.5</td><td>22.5</td><td>3.5</td><td>15.7</td><td>1.0</td><td></td></tr><tr><td>Less amount representing interest</td><td>13.3</td><td>0.1</td><td>12.8</td><td>0.1</td><td>12.0</td><td>0.5</td><td>11.3</td><td>0.1</td><td></td></tr><tr><td>Present value of future minimum lease payments</td><td>$ 49.9</td><td>$ 0.7</td><td>$ 24.2</td><td>$ 0.4</td><td>$ 10.5</td><td>$ 3.0</td><td>$ 4.4</td><td>$ 0.9</td><td></td></tr></table>



At December 31, 2018, future minimum rental payments, excluding executory costs, such as property taxes, state use taxes, insurance, and maintenance were as follows:

<table><tr><td>Operating Leases (Millions of Dollars)</td><td colspan="2">Eversource</td><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td><td colspan="2">PSNH</td></tr><tr><td>2019</td><td>$</td><td>11.5</td><td>$</td><td>1.5</td><td>$</td><td>7.2</td><td>$</td><td>0.5</td></tr><tr><td>2020</td><td></td><td>9.8</td><td></td><td>1.4</td><td></td><td>6.0</td><td></td><td>0.4</td></tr><tr><td>2021</td><td></td><td>8.7</td><td></td><td>1.2</td><td></td><td>5.3</td><td></td><td>0.4</td></tr><tr><td>2022</td><td></td><td>7.2</td><td></td><td>1.1</td><td></td><td>4.4</td><td></td><td>0.4</td></tr><tr><td>2023</td><td></td><td>4.7</td><td></td><td>0.5</td><td></td><td>3.1</td><td></td><td>0.2</td></tr><tr><td>Thereafter</td><td></td><td>32.7</td><td></td><td>0.2</td><td></td><td>29.5</td><td></td><td>0.3</td></tr><tr><td>Future minimum lease payments</td><td>$</td><td>74.6</td><td>$</td><td>5.9</td><td>$</td><td>55.5</td><td>$</td><td>2.2</td></tr></table>

<table><tr><td>Capital Leases (Millions of Dollars)</td><td colspan="2">Eversource</td><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td><td colspan="2">PSNH</td></tr><tr><td>2019</td><td>$</td><td>3.4</td><td>$</td><td>2.0</td><td>$</td><td>0.5</td><td>$</td><td>0.1</td></tr><tr><td>2020</td><td></td><td>3.4</td><td></td><td>2.0</td><td></td><td>0.5</td><td></td><td>0.1</td></tr><tr><td>2021</td><td></td><td>2.9</td><td></td><td>1.5</td><td></td><td>0.5</td><td></td><td>0.1</td></tr><tr><td>2022</td><td></td><td>1.5</td><td></td><td>—</td><td></td><td>0.6</td><td></td><td>0.1</td></tr><tr><td>2023</td><td></td><td>0.7</td><td></td><td>—</td><td></td><td>0.6</td><td></td><td>0.1</td></tr><tr><td>Thereafter</td><td></td><td>13.9</td><td></td><td>—</td><td></td><td>13.4</td><td></td><td>0.5</td></tr><tr><td>Future minimum lease payments</td><td></td><td>25.8</td><td></td><td>5.5</td><td></td><td>16.1</td><td></td><td>1.0</td></tr><tr><td>Less amount representing interest</td><td></td><td>13.8</td><td></td><td>1.0</td><td></td><td>12.4</td><td></td><td>0.1</td></tr><tr><td>Present value of future minimum lease payments</td><td>$</td><td>12.0</td><td>$</td><td>4.5</td><td>$</td><td>3.7</td><td>$</td><td>0.9</td></tr></table>

## 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:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">Eversource</td><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td><td colspan="2">PSNH</td></tr><tr><td>Carrying Amount</td><td>Fair Value</td><td>Carrying Amount</td><td>Fair Value</td><td>Carrying Amount</td><td>Fair Value</td><td>Fair Amount</td><td>Carrying Amount</td><td>Fair Value</td></tr><tr><td>As of December 31, 2019:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Preferred Stock Not Subject to Mandatory Redemption</td><td>$ 155.6</td><td>$ 162.0</td><td>$ 116.2</td><td>$ 117.8</td><td>$ 43.0</td><td>$ 44.2</td><td>$</td><td>—</td><td>$ —</td></tr><tr><td>Long-Term Debt</td><td>14,098.2</td><td>15,170.2</td><td>3,518.1</td><td>4,058.0</td><td>3,342.1</td><td>3,659.9</td><td>951.6</td><td>1,005.7</td><td></td></tr><tr><td>Rate Reduction Bonds</td><td>583.3</td><td>625.9</td><td>—</td><td>—</td><td>—</td><td>—</td><td>583.3</td><td>625.9</td><td></td></tr><tr><td>As of December 31, 2018:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Preferred Stock Not Subject to Mandatory Redemption</td><td>$ 155.6</td><td>$ 156.8</td><td>$ 116.2</td><td>$ 113.8</td><td>$ 43.0</td><td>$ 43.0</td><td>$</td><td>—</td><td>$ —</td></tr><tr><td>Long-Term Debt</td><td>13,086.1</td><td>13,154.9</td><td>3,254.0</td><td>3,429.2</td><td>2,944.8</td><td>3,024.1</td><td>805.2</td><td>819.5</td><td></td></tr><tr><td>Rate Reduction Bonds</td><td>635.7</td><td>645.8</td><td>—</td><td>—</td><td>—</td><td>—</td><td>635.7</td><td>645.8</td><td></td></tr></table>

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.



## 17. ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

The changes in accumulated other comprehensive income/(loss) by component, net of tax, are as follows:

<table><tr><td rowspan="2"></td><td colspan="6">For the Year Ended December 31, 2019</td><td colspan="6">For the Year Ended December 31, 2018</td></tr><tr><td>Qualified Cash Flow Hedging Instruments</td><td>Unrealized Gains/(Losses) on Marketable Securities</td><td>Defined Benefit Plans</td><td>Total</td><td>Qualified Cash Flow Hedging Instruments</td><td>Unrealized Losses on Marketable Securities</td><td>Defined Benefit Plans</td><td>Total</td><td></td><td></td><td></td></tr><tr><td>Eversource (Millions of Dollars)</td><td>$ (4.4)</td><td>$ (0.5)</td><td>$ (55.1)</td><td>$ (60.0)</td><td>$ (6.2)</td><td>$ —</td><td>$ (60.2)</td><td>$ (66.4)</td><td></td><td></td><td></td></tr><tr><td>Balance as of January 1st</td><td>—</td><td>1.2</td><td>(13.3)</td><td>(12.1)</td><td>—</td><td>(0.5)</td><td>0.3</td><td>(0.2)</td><td></td><td></td><td></td></tr><tr><td>OCI Before Reclassifications</td><td>1.4</td><td>—</td><td>5.6</td><td>7.0</td><td>1.8</td><td>—</td><td>4.8</td><td>6.6</td><td></td><td></td><td></td></tr><tr><td>Amounts Reclassified from AOCI</td><td>1.4</td><td>1.2</td><td>(7.7)</td><td>(5.1)</td><td>1.8</td><td>(0.5)</td><td>5.1</td><td>6.4</td><td></td><td></td><td></td></tr><tr><td>Net OCI</td><td>$ (3.0)</td><td>$ 0.7</td><td>$ (62.8)</td><td>$ (65.1)</td><td>$ (4.4)</td><td>$ (0.5)</td><td>$ (55.1)</td><td>$ (60.0)</td><td></td><td></td><td></td></tr></table>

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:

<table><tr><td rowspan="3">Eversource (Millions of Dollars)</td><td colspan="4">Amounts Reclassified from AOCI</td><td rowspan="3">Statements of Income Line Item Impacted</td></tr><tr><td colspan="3">For the Years Ended December 31,</td><td rowspan="2"></td></tr><tr><td>2019</td><td>2018</td><td>2017</td></tr><tr><td>Qualified Cash Flow Hedging Instruments</td><td>$ (2.5)</td><td>$ (2.8)</td><td>$ (3.3)</td><td>Interest Expense</td><td></td></tr><tr><td>Tax Effect</td><td>1.1</td><td>1.0</td><td>1.3</td><td>Income Tax Expense</td><td></td></tr><tr><td>Qualified Cash Flow Hedging Instruments, Net of Tax</td><td>$ (1.4)</td><td>$ (1.8)</td><td>$ (2.0)</td><td></td><td></td></tr><tr><td>Defined Benefit Plan Costs:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Amortization of Actuarial Losses</td><td>$ (5.7)</td><td>$ (6.0)</td><td>$ (6.2)</td><td>Other Income, Net (1)</td><td></td></tr><tr><td>Amortization of Prior Service Cost</td><td>(1.8)</td><td>(0.4)</td><td>(1.1)</td><td>Other Income, Net (1)</td><td></td></tr><tr><td>Total Defined Benefit Plan Costs</td><td>(7.5)</td><td>(6.4)</td><td>(7.3)</td><td></td><td></td></tr><tr><td>Tax Effect</td><td>1.9</td><td>1.6</td><td>2.8</td><td>Income Tax Expense</td><td></td></tr><tr><td>Defined Benefit Plan Costs, Net of Tax</td><td>$ (5.6)</td><td>$ (4.8)</td><td>$ (4.5)</td><td></td><td></td></tr><tr><td>Total Amounts Reclassified from AOCI, Net of Tax</td><td>$ (7.0)</td><td>$ (6.6)</td><td>$ (6.5)</td><td></td><td></td></tr></table>

(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.



## 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:

<table><tr><td rowspan="2"></td><td colspan="4">Shares</td></tr><tr><td colspan="2">Authorized as of December 31, 2019 and 2018</td><td colspan="2">Issued as of December 31,</td></tr><tr><td></td><td>Par Value</td><td>2019</td><td>2018</td><td></td></tr><tr><td>Eversource</td><td>$ 5</td><td>380,000,000</td><td>345,858,402</td><td>333,878,402</td></tr><tr><td>CL&amp;P</td><td>$ 10</td><td>24,500,000</td><td>6,035,205</td><td>6,035,205</td></tr><tr><td>NSTAR Electric</td><td>$ 1</td><td>100,000,000</td><td>200</td><td>200</td></tr><tr><td>PSNH</td><td>$ 1</td><td>100,000,000</td><td>301</td><td>301</td></tr></table>

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 $1.48 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.

## 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):

<table><tr><td rowspan="2">Series</td><td rowspan="2">Redemption Price Per Share</td><td colspan="2">Shares Outstanding as of December 31,</td><td colspan="3">As of December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2019</td><td>2018</td><td></td></tr><tr><td>CL&amp;P</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>$1.90</td><td>Series of 1947</td><td>$</td><td>52.50</td><td>163,912</td><td>163,912</td><td>$</td></tr><tr><td>$2.00</td><td>Series of 1947</td><td>$</td><td>54.00</td><td>336,088</td><td>336,088</td><td>16.8</td></tr><tr><td>$2.04</td><td>Series of 1949</td><td>$</td><td>52.00</td><td>100,000</td><td>100,000</td><td>5.0</td></tr><tr><td>$2.20</td><td>Series of 1949</td><td>$</td><td>52.50</td><td>200,000</td><td>200,000</td><td>10.0</td></tr><tr><td>3.90%</td><td>Series of 1949</td><td>$</td><td>50.50</td><td>160,000</td><td>160,000</td><td>8.0</td></tr><tr><td>$2.06</td><td>Series E of 1954</td><td>$</td><td>51.00</td><td>200,000</td><td>200,000</td><td>10.0</td></tr><tr><td>$2.09</td><td>Series F of 1955</td><td>$</td><td>51.00</td><td>100,000</td><td>100,000</td><td>5.0</td></tr><tr><td>4.50%</td><td>Series of 1956</td><td>$</td><td>50.75</td><td>104,000</td><td>104,000</td><td>5.2</td></tr><tr><td>4.96%</td><td>Series of 1958</td><td>$</td><td>50.50</td><td>100,000</td><td>100,000</td><td>5.0</td></tr><tr><td>4.50%</td><td>Series of 1963</td><td>$</td><td>50.50</td><td>160,000</td><td>160,000</td><td>8.0</td></tr><tr><td>5.28%</td><td>Series of 1967</td><td>$</td><td>51.43</td><td>200,000</td><td>200,000</td><td>10.0</td></tr><tr><td>$3.24</td><td>Series G of 1968</td><td>$</td><td>51.84</td><td>300,000</td><td>300,000</td><td>15.0</td></tr><tr><td>6.56%</td><td>Series of 1968</td><td>$</td><td>51.44</td><td>200,000</td><td>200,000</td><td>10.0</td></tr><tr><td>Total CL&amp;P</td><td></td><td></td><td></td><td>2,324,000</td><td>2,324,000</td><td>$</td></tr><tr><td>NSTAR Electric</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>4.25%</td><td>Series of 1956</td><td>$</td><td>103.625</td><td>180,000</td><td>180,000</td><td>18.0</td></tr><tr><td>4.78%</td><td>Series of 1958</td><td>$</td><td>102.80</td><td>250,000</td><td>250,000</td><td>25.0</td></tr><tr><td>Total NSTAR Electric</td><td></td><td></td><td></td><td>430,000</td><td>430,000</td><td>$</td></tr><tr><td>Fair Value Adjustment due to Merger with NSTAR</td><td></td><td></td><td></td><td></td><td></td><td>(3.6)</td></tr><tr><td>Other</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>6.00%</td><td>Series of 1958</td><td>$</td><td>100.00</td><td>23</td><td>23</td><td>—</td></tr><tr><td>Total Eversource - Noncontrolling Interest - Preferred Stock of Subsidiaries</td><td></td><td></td><td></td><td></td><td>$</td><td>155.6</td></tr></table>

## 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.



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:

<table><tr><td rowspan="2">Eversource (Millions of Dollars, except share information)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2019</td><td>2018</td><td>2017</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 909.1</td><td>$ 1,033.0</td><td>$ 988.0</td><td></td></tr><tr><td>Weighted Average Common Shares Outstanding:</td><td></td><td></td><td></td><td></td></tr><tr><td>Basic</td><td>321,416,086</td><td>317,370,369</td><td>317,411,097</td><td></td></tr><tr><td>Dilutive Effect of:</td><td></td><td></td><td></td><td></td></tr><tr><td>Share-Based Compensation Awards and Other</td><td>762,215</td><td>623,565</td><td>620,483</td><td></td></tr><tr><td>Equity Forward Sale Agreement</td><td>763,335</td><td>—</td><td>—</td><td></td></tr><tr><td>Total Dilutive Effect</td><td>1,525,550</td><td>623,565</td><td>620,483</td><td></td></tr><tr><td>Diluted</td><td>322,941,636</td><td>317,993,934</td><td>318,031,580</td><td></td></tr><tr><td>Basic EPS</td><td>$ 2.83</td><td>$ 3.25</td><td>$ 3.11</td><td></td></tr><tr><td>Diluted EPS</td><td>$ 2.81</td><td>$ 3.25</td><td>$ 3.11</td><td></td></tr></table>

## 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:

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="8">For the Year Ended December 31, 2019</td></tr><tr><td>Electric Distribution</td><td>Natural Gas Distribution</td><td>Electric Transmission</td><td>Water Distribution</td><td>Other</td><td>Eliminations</td><td>Total</td><td></td></tr><tr><td>Revenues from Contracts with Customers</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Retail Tariff Sales</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>$ 3,723.7</td><td>$ 555.1</td><td>$ —</td><td>$ 132.3</td><td>$ —</td><td>$ —</td><td>$ 4,411.1</td><td></td></tr><tr><td>Commercial</td><td>2,584.8</td><td>347.6</td><td>—</td><td>63.9</td><td>—</td><td>(4.3)</td><td>2,992.0</td><td></td></tr><tr><td>Industrial</td><td>331.8</td><td>96.9</td><td>—</td><td>4.5</td><td>—</td><td>(11.6)</td><td>421.6</td><td></td></tr><tr><td>Total Retail Tariff Sales Revenues</td><td>6,640.3</td><td>999.6</td><td>—</td><td>200.7</td><td>—</td><td>(15.9)</td><td>7,824.7</td><td></td></tr><tr><td>Wholesale Transmission Revenues</td><td>—</td><td>—</td><td>1,293.3</td><td>—</td><td>61.3</td><td>(1,085.2)</td><td>269.4</td><td></td></tr><tr><td>Wholesale Market Sales Revenues</td><td>215.7</td><td>55.4</td><td>—</td><td>4.1</td><td>—</td><td>—</td><td>275.2</td><td></td></tr><tr><td>Other Revenues from Contracts with Customers</td><td>54.8</td><td>2.8</td><td>13.2</td><td>7.0</td><td>967.2</td><td>(969.0)</td><td>76.0</td><td></td></tr><tr><td>Reserve for Revenues Subject to Refund</td><td>1.3</td><td>6.2</td><td>—</td><td>(2.8)</td><td>—</td><td>—</td><td>4.7</td><td></td></tr><tr><td>Total Revenues from Contracts with Customers</td><td>6,912.1</td><td>1,064.0</td><td>1,306.5</td><td>209.0</td><td>1,028.5</td><td>(2,070.1)</td><td>8,450.0</td><td></td></tr><tr><td>Alternative Revenue Programs</td><td>45.9</td><td>(4.9)</td><td>81.8</td><td>4.6</td><td>—</td><td>(74.2)</td><td>53.2</td><td></td></tr><tr><td>Other Revenues</td><td>18.5</td><td>3.1</td><td>0.7</td><td>1.0</td><td>—</td><td>—</td><td>23.3</td><td></td></tr><tr><td>Total Operating Revenues</td><td>$ 6,976.5</td><td>$ 1,062.2</td><td>$ 1,389.0</td><td>$ 214.6</td><td>$ 1,028.5</td><td>$ (2,144.3)</td><td>$ 8,526.5</td><td></td></tr></table>



For the Year Ended December 31, 2018

<table><tr><td>Eversource (Millions of Dollars)</td><td>Electric Distribution</td><td>Natural Gas Distribution</td><td>Electric Transmission</td><td>Water Distribution</td><td>Other</td><td>Eliminations</td><td>Total</td></tr><tr><td>Revenues from Contracts with Customers</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Retail Tariff Sales</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>$ 3,766.6</td><td>$ 542.5</td><td>$ —</td><td>$ 130.7</td><td>$ —</td><td>$ —</td><td>$ 4,439.8</td></tr><tr><td>Commercial</td><td>2,634.7</td><td>334.8</td><td>—</td><td>63.3</td><td>—</td><td>(4.5)</td><td>3,028.3</td></tr><tr><td>Industrial</td><td>351.9</td><td>96.0</td><td>—</td><td>4.4</td><td>—</td><td>(10.0)</td><td>442.3</td></tr><tr><td>Total Retail Tariff Sales Revenues</td><td>6,753.2</td><td>973.3</td><td>—</td><td>198.4</td><td>—</td><td>(14.5)</td><td>7,910.4</td></tr><tr><td>Wholesale Transmission Revenues</td><td>—</td><td>—</td><td>1,308.9</td><td>—</td><td>47.3</td><td>(1,092.2)</td><td>264.0</td></tr><tr><td>Wholesale Market Sales Revenues</td><td>179.5</td><td>57.5</td><td>—</td><td>4.1</td><td>—</td><td>—</td><td>241.1</td></tr><tr><td>Other Revenues from Contracts with Customers</td><td>65.9</td><td>(2.2)</td><td>12.6</td><td>7.2</td><td>889.0</td><td>(891.0)</td><td>81.5</td></tr><tr><td>Reserve for Revenues Subject to Refund</td><td>(12.3)</td><td>(8.3)</td><td>—</td><td>(3.7)</td><td>—</td><td>—</td><td>(24.3)</td></tr><tr><td>Total Revenues from Contracts with Customers</td><td>6,986.3</td><td>1,020.3</td><td>1,321.5</td><td>206.0</td><td>936.3</td><td>(1,997.7)</td><td>8,472.7</td></tr><tr><td>Alternative Revenue Programs</td><td>(47.0)</td><td>(1.2)</td><td>(35.2)</td><td>5.4</td><td>—</td><td>31.9</td><td>(46.1)</td></tr><tr><td>Other Revenues</td><td>17.9</td><td>3.1</td><td>—</td><td>0.6</td><td>—</td><td>—</td><td>21.6</td></tr><tr><td>Total Operating Revenues</td><td>$ 6,957.2</td><td>$ 1,022.2</td><td>$ 1,286.3</td><td>$ 212.0</td><td>$ 936.3</td><td>$ (1,965.8)</td><td>$ 8,448.2</td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">2019</td><td colspan="3">2018</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Revenues from Contracts with Customers</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Retail Tariff Sales</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>$ 1,837.1</td><td>$ 1,322.1</td><td>$ 564.5</td><td>$ 1,828.2</td><td>$ 1,380.9</td><td>$ 557.5</td></tr><tr><td>Commercial</td><td>922.9</td><td>1,349.4</td><td>314.6</td><td>928.1</td><td>1,391.5</td><td>316.9</td></tr><tr><td>Industrial</td><td>138.3</td><td>115.8</td><td>77.7</td><td>147.7</td><td>124.9</td><td>79.3</td></tr><tr><td>Total Retail Tariff Sales Revenues</td><td>2,898.3</td><td>2,787.3</td><td>956.8</td><td>2,904.0</td><td>2,897.3</td><td>953.7</td></tr><tr><td>Wholesale Transmission Revenues</td><td>587.1</td><td>517.3</td><td>188.9</td><td>620.6</td><td>488.8</td><td>199.5</td></tr><tr><td>Wholesale Market Sales Revenues</td><td>105.1</td><td>73.1</td><td>37.5</td><td>48.3</td><td>76.1</td><td>56.6</td></tr><tr><td>Other Revenues from Contracts with Customers</td><td>36.4</td><td>18.7</td><td>15.6</td><td>35.0</td><td>28.9</td><td>15.5</td></tr><tr><td>Reserve for Revenues Subject to Refund</td><td>—</td><td>—</td><td>1.3</td><td>—</td><td>—</td><td>(12.3)</td></tr><tr><td>Total Revenues from Contracts with Customers</td><td>3,626.9</td><td>3,396.4</td><td>1,200.1</td><td>3,607.9</td><td>3,491.1</td><td>1,213.0</td></tr><tr><td>Alternative Revenue Programs</td><td>77.5</td><td>41.6</td><td>8.6</td><td>(65.9)</td><td>0.9</td><td>(17.3)</td></tr><tr><td>Other Revenues</td><td>10.3</td><td>7.0</td><td>1.9</td><td>8.5</td><td>8.3</td><td>1.1</td></tr><tr><td>Eliminations</td><td>(482.1)</td><td>(400.4)</td><td>(144.7)</td><td>(454.3)</td><td>(387.4)</td><td>(149.2)</td></tr><tr><td>Total Operating Revenues</td><td>$ 3,232.6</td><td>$ 3,044.6</td><td>$ 1,065.9</td><td>$ 3,096.2</td><td>$ 3,112.9</td><td>$ 1,047.6</td></tr></table>

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.

## 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.



For the Year Ended December 31, 2019

<table><tr><td>Eversource
(Millions of Dollars)</td><td>Electric
Distribution</td><td>Natural Gas
Distribution</td><td>Electric
Transmission</td><td>Water
Distribution</td><td>Other</td><td>Eliminations</td><td>Total</td></tr><tr><td>Operating Revenues</td><td>$ 6,976.5</td><td>$ 1,062.2</td><td>$ 1,389.0</td><td>$ 214.6</td><td>$ 1,028.5</td><td>$ (2,144.3)</td><td>$ 8,526.5</td></tr><tr><td>Depreciation and Amortization</td><td>(651.3)</td><td>(68.3)</td><td>(253.3)</td><td>(46.9)</td><td>(63.2)</td><td>2.3</td><td>(1,080.7)</td></tr><tr><td>Impairment of Northern Pass Transmission</td><td>—</td><td>—</td><td>(239.6)</td><td>—</td><td>—</td><td>—</td><td>(239.6)</td></tr><tr><td>Other Operating Expenses</td><td>(5,525.1)</td><td>(830.8)</td><td>(411.2)</td><td>(101.0)</td><td>(891.3)</td><td>2,143.7</td><td>(5,615.7)</td></tr><tr><td>Operating Income</td><td>800.1</td><td>163.1</td><td>484.9</td><td>66.7</td><td>74.0</td><td>1.7</td><td>1,590.5</td></tr><tr><td>Interest Expense</td><td>(206.4)</td><td>(47.4)</td><td>(125.7)</td><td>(34.6)</td><td>(170.3)</td><td>51.2</td><td>(533.2)</td></tr><tr><td>Interest Income</td><td>13.3</td><td>0.1</td><td>1.5</td><td>—</td><td>48.7</td><td>(50.8)</td><td>12.8</td></tr><tr><td>Other Income, Net</td><td>46.8</td><td>1.6</td><td>29.2</td><td>0.4</td><td>1,041.5</td><td>(999.5)</td><td>120.0</td></tr><tr><td>Income Tax (Expense)/Benefit</td><td>(135.9)</td><td>(21.2)</td><td>(130.5)</td><td>2.4</td><td>11.7</td><td>—</td><td>(273.5)</td></tr><tr><td>Net Income</td><td>517.9</td><td>96.2</td><td>259.4</td><td>34.9</td><td>1,005.6</td><td>(997.4)</td><td>916.6</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>(4.6)</td><td>—</td><td>(2.9)</td><td>—</td><td>—</td><td>—</td><td>(7.5)</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 513.3</td><td>$ 96.2</td><td>$ 256.5</td><td>$ 34.9</td><td>$ 1,005.6</td><td>$ (997.4)</td><td>$ 909.1</td></tr><tr><td>Total Assets (as of)</td><td>$ 22,541.9</td><td>$ 4,345.5</td><td>$ 10,904.0</td><td>$ 2,351.7</td><td>$ 20,469.6</td><td>$ (19,488.8)</td><td>$ 41,123.9</td></tr><tr><td>Cash Flows Used for Investments in Plant</td><td>$ 1,104.2</td><td>$ 460.2</td><td>$ 987.0</td><td>$ 118.0</td><td>$ 242.1</td><td>$ —</td><td>$ 2,911.5</td></tr></table>

For the Year Ended December 31, 2018

<table><tr><td>Eversource
(Millions of Dollars)</td><td>Electric
Distribution</td><td>Natural Gas
Distribution</td><td>Electric
Transmission</td><td>Water
Distribution</td><td>Other</td><td>Eliminations</td><td>Total</td></tr><tr><td>Operating Revenues (1)</td><td>$ 6,957.2</td><td>$ 1,022.2</td><td>$ 1,286.3</td><td>$ 212.0</td><td>$ 936.3</td><td>$ (1,965.8)</td><td>$ 8,448.2</td></tr><tr><td>Depreciation and Amortization</td><td>(671.8)</td><td>(75.0)</td><td>(231.8)</td><td>(46.5)</td><td>(49.1)</td><td>2.2</td><td>(1,072.0)</td></tr><tr><td>Other Operating Expenses (1)</td><td>(5,548.6)</td><td>(787.6)</td><td>(375.5)</td><td>(99.8)</td><td>(831.5)</td><td>1,966.7</td><td>(5,676.3)</td></tr><tr><td>Operating Income</td><td>736.8</td><td>159.6</td><td>679.0</td><td>65.7</td><td>55.7</td><td>3.1</td><td>1,699.9</td></tr><tr><td>Interest Expense</td><td>(202.8)</td><td>(44.1)</td><td>(120.6)</td><td>(34.3)</td><td>(129.3)</td><td>32.3</td><td>(498.8)</td></tr><tr><td>Interest Income</td><td>18.7</td><td>—</td><td>2.4</td><td>—</td><td>30.3</td><td>(33.3)</td><td>18.1</td></tr><tr><td>Other Income/(Loss), Net</td><td>67.5</td><td>7.1</td><td>31.1</td><td>(0.4)</td><td>1,185.3</td><td>(1,180.3)</td><td>110.3</td></tr><tr><td>Income Tax (Expense)/Benefit</td><td>(160.2)</td><td>(29.4)</td><td>(161.8)</td><td>(0.1)</td><td>62.5</td><td>—</td><td>(289.0)</td></tr><tr><td>Net Income</td><td>460.0</td><td>93.2</td><td>430.1</td><td>30.9</td><td>1,204.5</td><td>(1,178.2)</td><td>1,040.5</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>(4.6)</td><td>—</td><td>(2.9)</td><td>—</td><td>—</td><td>—</td><td>(7.5)</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 455.4</td><td>$ 93.2</td><td>$ 427.2</td><td>$ 30.9</td><td>$ 1,204.5</td><td>$ (1,178.2)</td><td>$ 1,033.0</td></tr><tr><td>Total Assets (as of)</td><td>$ 21,389.1</td><td>$ 3,904.9</td><td>$ 10,285.0</td><td>$ 2,253.0</td><td>$ 17,874.2</td><td>$ (17,464.9)</td><td>$ 38,241.3</td></tr><tr><td>Cash Flows Used for Investments in Plant (2)</td><td>$ 961.3</td><td>$ 351.5</td><td>$ 976.2</td><td>$ 102.3</td><td>$ 178.6</td><td>$ —</td><td>$ 2,569.9</td></tr></table>

For the Year Ended December 31, 2017

<table><tr><td>Eversource
(Millions of Dollars)</td><td>Electric
Distribution</td><td>Natural Gas
Distribution</td><td>Electric
Transmission</td><td>Water
Distribution</td><td>Other</td><td>Eliminations</td><td>Total</td></tr><tr><td>Operating Revenues (1)</td><td>$ 5,542.9</td><td>$ 947.3</td><td>$ 1,301.7</td><td>$ 15.9</td><td>$ 931.0</td><td>$ (986.8)</td><td>$ 7,752.0</td></tr><tr><td>Depreciation and Amortization</td><td>(542.6)</td><td>(72.9)</td><td>(209.4)</td><td>(3.7)</td><td>(37.4)</td><td>2.2</td><td>(863.8)</td></tr><tr><td>Other Operating Expenses (1)</td><td>(4,072.6)</td><td>(716.4)</td><td>(382.8)</td><td>(8.3)</td><td>(806.6)</td><td>986.7</td><td>(5,000.0)</td></tr><tr><td>Operating Income</td><td>927.7</td><td>158.0</td><td>709.5</td><td>3.9</td><td>87.0</td><td>2.1</td><td>1,888.2</td></tr><tr><td>Interest Expense</td><td>(186.3)</td><td>(43.1)</td><td>(115.1)</td><td>(3.1)</td><td>(90.0)</td><td>15.8</td><td>(421.8)</td></tr><tr><td>Interest Income</td><td>7.3</td><td>0.1</td><td>1.8</td><td>0.1</td><td>15.7</td><td>(16.7)</td><td>8.3</td></tr><tr><td>Other Income, Net</td><td>41.6</td><td>3.8</td><td>27.3</td><td>—</td><td>1,113.0</td><td>(1,086.0)</td><td>99.7</td></tr><tr><td>Income Tax Expense</td><td>(288.3)</td><td>(44.2)</td><td>(228.7)</td><td>(2.1)</td><td>(15.5)</td><td>(0.1)</td><td>(578.9)</td></tr><tr><td>Net Income/(Loss)</td><td>502.0</td><td>74.6</td><td>394.8</td><td>(1.2)</td><td>1,110.2</td><td>(1,084.9)</td><td>995.5</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>(4.6)</td><td>—</td><td>(2.9)</td><td>—</td><td>—</td><td>—</td><td>(7.5)</td></tr><tr><td>Net Income/(Loss) Attributable to Common Shareholders</td><td>$ 497.4</td><td>$ 74.6</td><td>$ 391.9</td><td>$ (1.2)</td><td>$ 1,110.2</td><td>$ (1,084.9)</td><td>$ 988.0</td></tr><tr><td>Cash Flows Used for Investments in Plant</td><td>$ 1,020.7</td><td>$ 298.2</td><td>$ 867.6</td><td>$ 16.0</td><td>$ 145.6</td><td>$ —</td><td>$ 2,348.1</td></tr></table>



(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.

<table><tr><td>(Pro forma amounts in millions, except share amounts)</td><td>For the Year Ended December 31, 2017</td></tr><tr><td>Operating Revenues</td><td>$ 7,947.7</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>1,019.1</td></tr><tr><td>Basic EPS</td><td>3.21</td></tr><tr><td>Diluted EPS</td><td>3.20</td></tr></table>

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:

<table><tr><td>(Billions of Dollars)</td><td>Electric Distribution</td><td>Electric Transmission</td><td>Natural Gas Distribution</td><td>Water Distribution</td><td>Total</td></tr><tr><td>Goodwill</td><td>$ 2.5</td><td>$ 0.6</td><td>$ 0.4</td><td>$ 0.9</td><td>$ 4.4</td></tr></table>



## 26. QUARTERLY FINANCIAL DATA (UNAUDITED)

<table><tr><td rowspan="2">Eversource (Millions of Dollars, except per share information)</td><td colspan="8">2019</td><td colspan="4">2018</td></tr><tr><td colspan="2">March 31,</td><td colspan="2">June 30, (2)</td><td colspan="2">September 30,</td><td colspan="2">December 31,</td><td colspan="2">March 31,</td><td>June 30,</td><td>September 30,</td></tr><tr><td>Operating Revenues</td><td>$ 2,415.8</td><td>$ 1,884.5</td><td>$ 2,175.8</td><td>$ 2,050.4</td><td>$ 2,050.4</td><td>$ 2,288.0</td><td>$ 1,853.9</td><td>$ 2,271.4</td><td>$ 2,034.9</td><td></td><td></td><td></td></tr><tr><td>Operating Income</td><td>494.7</td><td>151.0</td><td>509.2</td><td>435.6</td><td>442.5</td><td>391.4</td><td>466.0</td><td>400.0</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Income</td><td>310.6</td><td>33.3</td><td>320.8</td><td>251.9</td><td>271.4</td><td>244.6</td><td>291.3</td><td>233.2</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>308.7</td><td>31.5</td><td>318.9</td><td>250.0</td><td>269.5</td><td>242.8</td><td>289.4</td><td>231.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Basic EPS (1)</td><td>$ 0.97</td><td>$ 0.10</td><td>$ 0.98</td><td>$ 0.77</td><td>$ 0.85</td><td>$ 0.76</td><td>$ 0.91</td><td>$ 0.73</td><td></td><td></td><td></td><td></td></tr><tr><td>Diluted EPS (1)</td><td>$ 0.97</td><td>$ 0.10</td><td>$ 0.98</td><td>$ 0.76</td><td>$ 0.85</td><td>$ 0.76</td><td>$ 0.91</td><td>$ 0.73</td><td></td><td></td><td></td><td></td></tr></table>

(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.

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="8">2019</td><td colspan="4">2018</td></tr><tr><td colspan="2">March 31,</td><td colspan="2">June 30,</td><td colspan="2">September 30,</td><td colspan="2">December 31,</td><td colspan="2">March 31,</td><td>June 30,</td><td>September 30,</td></tr><tr><td>CL&amp;P</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Revenues</td><td>$ 849.2</td><td>$ 740.8</td><td>$ 853.9</td><td>$ 788.7</td><td>$ 785.0</td><td>$ 694.9</td><td>$ 865.0</td><td>$ 751.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Income</td><td>171.8</td><td>166.8</td><td>190.3</td><td>152.7</td><td>157.2</td><td>163.1</td><td>172.7</td><td>142.8</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Income</td><td>110.5</td><td>104.8</td><td>111.7</td><td>83.9</td><td>98.6</td><td>99.7</td><td>100.3</td><td>79.1</td><td></td><td></td><td></td><td></td></tr><tr><td>NSTAR Electric</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Revenues</td><td>$ 797.6</td><td>$ 681.9</td><td>$ 878.7</td><td>$ 686.4</td><td>$ 770.1</td><td>$ 690.7</td><td>$ 939.5</td><td>$ 712.6</td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Income</td><td>137.8</td><td>134.2</td><td>219.4</td><td>135.5</td><td>119.0</td><td>133.6</td><td>205.5</td><td>126.0</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Income</td><td>94.0</td><td>89.7</td><td>154.9</td><td>93.4</td><td>77.1</td><td>87.9</td><td>140.6</td><td>77.5</td><td></td><td></td><td></td><td></td></tr><tr><td>PSNH</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Revenues</td><td>$ 276.4</td><td>$ 240.9</td><td>$ 280.4</td><td>$ 268.2</td><td>$ 267.4</td><td>$ 235.1</td><td>$ 290.2</td><td>$ 254.9</td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Income</td><td>49.7</td><td>46.3</td><td>64.5</td><td>56.0</td><td>55.8</td><td>46.9</td><td>56.5</td><td>37.2</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Income</td><td>32.8</td><td>26.9</td><td>40.9</td><td>33.4</td><td>35.1</td><td>25.8</td><td>40.7</td><td>14.3</td><td></td><td></td><td></td><td></td></tr></table>

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.

## 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.

Set forth below is certain information concerning Eversource Energy’s executive officers:

<table><tr><td>Name</td><td>Age</td><td>Title</td></tr><tr><td>James J. Judge</td><td>64</td><td>Chairman of the Board, President and Chief Executive Officer and a Trustee of Eversource Energy; Chairman and director of CL&amp;P</td></tr><tr><td>Philip J. Lembo</td><td>64</td><td>Executive Vice President and Chief Financial Officer of Eversource Energy and CL&amp;P; director of CL&amp;P</td></tr><tr><td>Gregory B. Butler</td><td>62</td><td>Executive Vice President and General Counsel of Eversource Energy and CL&amp;P; director of CL&amp;P</td></tr><tr><td>Christine M. Carmody</td><td>57</td><td>Executive Vice President-Human Resources and Information Technology of Eversource Energy</td></tr><tr><td>Joseph R. Nolan, Jr.</td><td>56</td><td>Executive Vice President-Strategy, Customer and Corporate Relations of Eversource Energy</td></tr><tr><td>Werner J. Schweiger</td><td>60</td><td>Executive Vice President and Chief Operating Officer of Eversource Energy; Chief Executive Officer and director of CL&amp;P</td></tr><tr><td>Jay S. Buth</td><td>50</td><td>Vice President, Controller and Chief Accounting Officer of Eversource Energy and CL&amp;P</td></tr></table>

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.



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

The information required by this Item 10 for CL&P has been omitted from this report but is set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.

## 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 required by this Item 11 for CL&P has been omitted from this report but is set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.

## 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

The information required by this Item 12 for CL&P has been omitted from this report but is set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.



## 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:

<table><tr><td>Plan Category</td><td>Number of securities to be issued upon exercise of outstanding options, warrants and rights (1)</td><td>Weighted-average exercise price of outstanding options, warrants and rights (2)</td><td>Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (1))</td></tr><tr><td>Equity compensation plans approved by security holders</td><td>1,261,070</td><td>$—</td><td>3,302,526</td></tr><tr><td>Equity compensation plans not approved by security holders (3)</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Total</td><td>1,261,070</td><td>$—</td><td>3,302,526</td></tr></table>

(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

The information required by this Item 13 for CL&P has been omitted from this report but is set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.

## 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

The information required by this Item 14 for CL&P, NSTAR Electric and PSNH has been omitted from this report but is set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.



## 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

Eversource Energy (Parent) Statements of Income for the Years Ended December 31, 2019, 2018 and 2017

Eversource Energy (Parent) Statements of Comprehensive Income for the Years Ended December 31, 2019, 2018 and 2017

Eversource Energy (Parent) Statements of Cash Flows for the Years Ended December 31, 2019, 2018 and 2017

II. Valuation and Qualifying Accounts and Reserves for Eversource, CL&P, NSTAR Electric and PSNH for 2019, 2018 and 2017

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

The schedules have been omitted from this report because they are not required. They are set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.

## Item 16. Form 10-K Summary

Not applicable.



## 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 (+).

The portion of the Exhibit Index listing exhibits of CL&P, NSTAR Electric and PSNH has been omitted from this report but is set forth in the Annual Report on Form 10-K for 2019 filed with the SEC on a combined basis with Eversource Energy on February 27, 2020. Such report is also available in the Investors section at www.eversource.com.

Exhibit Number ___ Description ___

3. Articles of Incorporation and By-Laws

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)

4. Instruments defining the rights of security holders, including indentures

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)

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



(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

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)

 \( ^{*} \) +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)

+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 NEWS 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)/15d-14(a) Certifications

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

 \( ^{*} $ 32 18 U.S.C. Section 1350 Certifications

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

 \( ^{*} $ 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



# 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.

<table><tr><td>Signature</td><td>Title</td><td>Date</td></tr><tr><td>/s/ James J. Judge</td><td>Chairman of the Board, President and Chief Executive Officer and a Trustee (Principal Executive Officer)</td><td>February 26, 2020</td></tr><tr><td>/s/ Philip J. Lembo</td><td>Executive Vice President and Chief Financial Officer (Principal Financial Officer)</td><td>February 26, 2020</td></tr><tr><td>/s/ Jay S. Buth</td><td>Vice President, Controller and Chief Accounting Officer</td><td>February 26, 2020</td></tr><tr><td>/s/ Jay S. BUTH</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>/s/ Cotton M. Cleveland</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>Cotton M. Cleveland</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>/s/ Sanford Cloud, Jr.</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>Sanford Cloud, Jr.</td><td>Trustee</td><td>February 26, 2020</td><td></td></tr></table>



<table><tr><td>Signature</td><td>Title</td><td>Date</td></tr><tr><td>/s/ James S. DiStasio</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>James S. DiStasio</td><td></td><td></td></tr><tr><td>/s/ Francis A. Doyle</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>Francis A. Doyle</td><td></td><td></td></tr><tr><td>/s/ Linda Dorcena Forry</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>Linda Dorcena Forry</td><td></td><td></td></tr><tr><td>/s/ John Y. Kim</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>John Y. Kim</td><td></td><td></td></tr><tr><td>/s/ Kenneth R. Leibler</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>Kenneth R. Leibler</td><td></td><td></td></tr><tr><td>/s/ David H. Long</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>David H. Long</td><td></td><td></td></tr><tr><td>/s/ William C. Van Faasen</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>William C. Van Faasen</td><td></td><td></td></tr><tr><td>/s/ Frederica M. Williams</td><td>Trustee</td><td>February 26, 2020</td></tr><tr><td>Frederica M. Williams</td><td></td><td></td></tr></table>



# 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)



# 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)



# 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.



## Eversource Energy
Trustees

James J. Judge
Chairman of the Board,
President and Chief Executive Officer,
Eversource Energy

Cotton M. Cleveland
President, Mather Associates

Sanford Cloud, Jr.*
Chairman and Chief Executive Officer,
The Cloud Company, LLC

James S. DiStasio
Retired Senior Vice Chairman and
Americas Chief Operating Officer,
Ernst & Young

Francis A. Doyle
Chairman and Chief Executive Officer,
Connell Limited Partnership

Linda Dorcena Forry
Vice President, Diversity, Inclusion & Community
for the Northeast,
Suffolk Construction

John Y. Kim
Managing Partner, Brewer Lane Ventures, LLC

Kenneth R. Leibler
Chairman,
The Putnam Mutual Funds

David H. Long
Chairman, President and Chief Executive Officer,
Liberty Mutual Holding Company Inc.

William C. Van Faasen
Chairman Emeritus,
Blue Cross Blue Shield of Massachusetts Inc.

Frederica M. Williams
President and Chief Executive Officer,
Whittier Street Health Center

 \( ^{*} \) Lead Trustee

## Eversource Energy
Executive Officers

James J. Judge
Chairman of the Board,
President and Chief Executive Officer

Gregory B. Butler
Executive Vice President and General Counsel

Christine M. Carmody
Executive Vice President – Human Resources and Information Technology

Philip J. Lembo
Executive Vice President and Chief Financial Officer

Joseph R. Nolan, Jr.
Executive Vice President – Strategy, Customer and Corporate Relations

Werner J. Schweiger
Executive Vice President and Chief Operating Officer



## Shareholder Information

## Shareholders

As of December 31, 2019, there were 33,628 common shareholders of record of Eversource Energy holding an aggregate of 329,880,645 common shares.

## Transfer Agent and Registrar

Computershare Investor Services
P.O. Box 505005
Louisville, KY 40233-5005

1-800-999-7269

TDD for hearing impaired: 1-800-952-9245

## Shareholder Account Access

We have partnered with Computershare to offer you online access to your important shareowner communications in a single secure place. You can manage your account online via the Investor Center website, Computershare's web-based tool for shareholders, at www.computershare.com/investor. Through free around-the-clock access to the Investor Center website, you can view your account, access forms and request a variety of account transactions.

## Investor Relations

You may contact our Investor Relations Department:

Jeffrey Kotkin: 860-665-5154

Barbara Nieman: 860-665-3249

John Gavin: 781-441-8118

www.eversource.com

## Dividend Reinvestment Plan

Eversource offers a dividend reinvestment and share purchase plan. This plan is sponsored by the company and not only offers the reinvestment of dividends but provides both registered shareholders and interested first-time investors an affordable alternative for buying and selling Eversource common shares. To request an enrollment package, please call 1-800-999-7269 or log into: www.computershare.com/investor

## Direct Deposit for Quarterly Dividends

Direct deposit provides the convenience of automatic and immediate access to your funds, while eliminating the possibility for mail delays and lost, stolen or destroyed checks. This service is free of charge to you. Please call 1-800-999-7269 to request an enrollment form.

## Common Share Dividend Payment Dates

Last business day of March, June, September and December.

## Common Share Information

The common shares of Eversource Energy are listed on the New York Stock Exchange. The ticker symbol is "ES." The high and low daily prices and dividends paid for the past two years, by quarters, are shown in the table below.

<table><tr><td>Year</td><td>Quarter</td><td>High</td><td>Low</td><td>Quarterly Dividend per Share</td></tr><tr><td rowspan="4">2019</td><td>First</td><td>$72.26</td><td>$63.10</td><td>$0.535</td></tr><tr><td>Second</td><td>$77.87</td><td>$69.09</td><td>$0.535</td></tr><tr><td>Third</td><td>$85.93</td><td>$74.77</td><td>$0.535</td></tr><tr><td>Fourth</td><td>$86.55</td><td>$78.58</td><td>$0.535</td></tr><tr><td rowspan="4">2018</td><td>First</td><td>$64.99</td><td>$55.93</td><td>$0.505</td></tr><tr><td>Second</td><td>$60.89</td><td>$52.76</td><td>$0.505</td></tr><tr><td>Third</td><td>$63.88</td><td>$57.49</td><td>$0.505</td></tr><tr><td>Fourth</td><td>$70.53</td><td>$60.56</td><td>$0.505</td></tr></table>

## Corporate Governance

For information on Corporate Governance at Eversource, go to our website, www.eversource.com, and select "Investors" and see "Corporate Governance" options.



Eversource would like to offer special thanks to Sandy Cloud, who is retiring from our Board of Trustees after 20 years of exceptional service to our company, including the last eight years as lead trustee. Sandy always offered wise counsel to this company’s leadership as we pursued new opportunities and navigated challenges.




Forbes 2020

AMERICA'S MOST RESPONSIBLE COMPANIES 2020

Newsweek

statista

Institutional Investor
2020 ALL-AMERICA EXECUTIVE TEAM
MOST HONORED COMPANY
EVERSOURCE ENERGY
#1 utility on the Forbes/JUST Capital
Most Just Companies list, honoring our
combination of corporate social
responsibility and business success.

#1 energy company on Newsweek’s list of Most Responsible Companies, recognizing our commitment to corporate social responsibility.

Rated by institutional investors as one of the top two US utilities in multiple categories related to executive leadership, sustainability, governance and investor relations.



BARRON'S
Most
Sustainable
Companies
2020

One of only four energy companies on the Barron's 100 Most Sustainable Companies list, based on an evaluation of more than 230 performance indicators that address environmental, social and corporate governance issues.