Eversource Energy (ES, NYSE)
Industry: Utilities - Regulated Electric
Annual report, fiscal year 2017


## 2017
Annual Report

## EVERSURCE
ENERGY






Earnings Per Share (1)



(1) Represents diluted earnings per share.

Dividends Per Share



## Total Shareholder Return

(Assumes $100 invested on December 31, 2007 with all dividends reinvested)






## Selected Financial Data

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

<table><tr><td></td><td>2017</td><td>2016</td></tr><tr><td>Operating Revenues</td><td>$ 7,751,952</td><td>$ 7,639,129</td></tr><tr><td>Operating Income</td><td>$ 1,918,154</td><td>$ 1,859,859</td></tr><tr><td>Net Income Attributable to ES Common Shares</td><td>$ 987,996</td><td>$ 942,302</td></tr><tr><td>Diluted Earnings per Common Share</td><td>$ 3.11</td><td>$ 2.96</td></tr><tr><td>Diluted Common Shares Outstanding (Weighted Average)</td><td>318,031,580</td><td>318,454,239</td></tr><tr><td>Dividends Paid per Share</td><td>$ 1.90</td><td>$ 1.78</td></tr><tr><td>Sales of Electricity (Regulated Retail, kWh-millions)</td><td>52,246</td><td>53,642</td></tr><tr><td>Electric Customers (As of Year End)</td><td>3,187,126</td><td>3,167,817</td></tr><tr><td>Total Sales of Natural Gas (million cubic feet)</td><td>101,026</td><td>98,042</td></tr><tr><td>Natural Gas Customers (As of Year End)</td><td>524,628</td><td>518,953</td></tr><tr><td>Water Customers (As of Year End) (1)</td><td>227,098</td><td>-</td></tr><tr><td>Investments in Property, Plant and Equipment</td><td>$ 2,348,105</td><td>$ 1,976,867</td></tr><tr><td>Property, Plant and Equipment, Net (As of Year End)</td><td>$ 23,617,463</td><td>$ 21,350,510</td></tr><tr><td>Market Capitalization (As of Year End)</td><td>$ 20,020,845</td><td>$ 17,501,603</td></tr><tr><td>Share Price (As of Year End)</td><td>$ 63.18</td><td>$ 55.23</td></tr></table>

(1) Aquarion Water Company became a wholly-owned subsidiary of Eversource Energy on December 4, 2017.



## 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



## Chairman's Letter

Dear Shareholder,

Eversource experienced an outstanding year in 2017 providing our customers with top-tier service and progressing towards our goal of being the best energy company in the nation. We achieved excellent financial performance, sold our New Hampshire generation facilities, and with the addition of the Aquarion Water Company, entered a new business line with many growth opportunities, becoming the only U.S. electric utility to also own a water utility.

The accomplishment we are most proud of is achieving our best year ever for employee safety. In a year of extreme weather events and mutual aid deployments from Florida to Maine, Eversource employees reduced safety-related incidents by 37 percent compared to 2016, which was previously the best year ever. It is a remarkable achievement.

Our employees also responded when we asked them to further improve reliability for our electric customers. The result was that our customers experienced service interruptions on average only about once every year-and-a-half, placing Eversource in the top quartile for electric reliability among our peers.

Our work on behalf of our communities also involves our efforts to become the catalyst for clean energy development in New England. We can report progress on multiple fronts in 2017, including approval of the sale of approximately 1,100 megawatts of fossil generation in New Hampshire. As we exited that business, we began construction of 62 megawatts of solar generation in Massachusetts, which we expect to complete in 2018. We've initiated two new clean energy initiatives for our customers: the build-out of infrastructure for electric vehicle charging stations and the installation of large-scale battery storage on Cape Cod and Martha's Vineyard.

With our partner Ørsted, we bid into a precedent-setting Massachusetts RFP for off-shore wind. A decision on the RFP is expected in April 2018. Our Bay State Wind partnership would supply power from a 300-square-mile tract of the Atlantic Ocean that is 15-25 miles south of Martha's Vineyard. The tract could host state-of-the-art wind turbines capable of producing at least 2,000 megawatts and supply up to 500,000 households with power.



## Corporate Credit Rating

Eversource vs EEI Index

Since 2011, S&P has raised our corporate credit rating by three notches. We are now alone at the top of the industry.



Our other major clean energy project, Northern Pass Transmission (NPT), recorded several successes in 2017, but encountered a significant setback in early 2018. NPT is a 192-mile, $1.6 billion transmission project designed to import 1,090 megawatts of clean hydroelectric power into a New England market that is focused on replacing carbon-emitting generation. In 2017, NPT received a Presidential Permit from the U.S. Department of Energy and a positive final Record of Decision from the U.S. Forest Service. However, on February 1, 2018, the New Hampshire Site Evaluation Committee (NHSEC) rejected the project. NPT would provide enormous economic, environmental and fuel diversity benefits to New Hampshire and New England as a whole, and we continue to work on a possible path forward for this important project.

Reducing greenhouse gas emissions not only involves enabling clean generation and transportation, it also involves helping our customers be more efficient with the energy they consume. In 2017, we again spent about $500 million on energy efficiency programs, with proven results. Consumption among our 3.2 million electric customers fell by more than 2 percent, even as the number of electric customers we serve grew by nearly 1 percent. We remain the nation's top provider of energy efficiency programs as determined by the sustainability advocacy organization Ceres. Partly due to those programs, Eversource was nationally recognized for its leadership in corporate sustainability and environmental performance, placing 20th among 500 U.S. companies in Newsweek magazine's annual Green Rankings list.
2017 was another year of delivering solid performance to our shareholders. We reported earnings of $3.11 per share, compared to $2.96 in 2016, an increase of 15 cents, or 5.1 percent. This earnings growth supports our dividend growth, and in 2017, we raised our annualized common dividend by 12 cents, or 6.7 percent, to $1.90 per share. This action was followed in February 2018 with the announcement of another 12-cent increase to an annualized rate of $2.02.

Our total return to shareholders – the combination of dividends paid and share price appreciation – was 18 percent for 2017, far exceeding the 11.7 percent return for the industry, as represented by the EEI Index of 43 companies. 2017 was the eighth time in the last nine years that we have achieved a “double-digit” total return for our shareholders. Only two other companies within our sector can match this consistent level of achievement.

And we have accomplished this performance without taking on excessive risk. In 2017, Standard and Poor’s raised our corporate credit rating to “A+” with a stable outlook, two notches above any of our electric utility peers. Strong credit ratings enable better access to capital markets and lower interest costs, benefitting our customers in the form of lower prices.

We invested a record $2.5 billion in our electric and natural gas delivery systems and customer service infrastructure in 2017. We continued to support the reliability of the regional electric system






with enhanced tree trimming and resiliency work, and with the completion of regional transmission projects, such as the Merrimack Valley project in New Hampshire.

We continued to grow our natural gas network installing nearly 43 miles of new pipeline in Connecticut and Massachusetts and adding more than 10,000 new heating customers for the fifth year in a row. Consistent with our sustainability strategy, we accelerated pipeline replacement in both states to reduce methane emissions, investing $107 million in 2017 to replace 61 miles of cast iron and steel pipe with safer, more durable plastic better able to handle fluctuations in temperatures and resist corrosion. Our pipeline replacements have more than doubled in scope over the past five years, improving system safety and the environment, and lowering operating costs.
Our addition of the Aquarion Water Company represents a unique convergence of three industries. Aquarion serves nearly 230,000 water customers in Connecticut, Massachusetts and New Hampshire, many of whom are already Eversource Energy customers. Similar to the electric and natural gas business, water utilities face the challenge of making significant investments to replace aging infrastructure and meet changing environmental standards.



We are pleased that our regulators recognize the benefits of our significant system investments to improve customer service in an increasingly digital economy and endorse our actions. In Massachusetts, approval of a five-year electric distribution rate plan allows us to continue this spending while providing adequate revenues to support our growing investments. In Connecticut, we achieved the first electric rate case settlement in 30 years in an agreement that will be in effect through 2020. We filed the agreement with Connecticut regulators and expect approval of the three-year plan in April, which calls for more than $350 million a year of new investment in our Connecticut distribution system. Revenue increases to support our infrastructure investments have been significantly tempered by the benefits of federal tax reform. In February, we were the first utility in the nation to return the benefits of federal tax reform to customers when we reduced our previously approved Massachusetts electric revenue levels and our Connecticut electric revenue increase request to reflect the lower tax rate.

Becoming the top energy company involves more than achieving high levels of financial and operating performance. We continue to execute a strategic plan to advance diversity and inclusion, from our expanded workforce across all our operations, to our Board of Trustees. A diverse, engaged workforce and inclusive culture contributes to our success and sustainability.

We remain committed partners in our communities, with about $16 million in financial donations and grants in 2017. This includes our support of low-income housing development in Connecticut and the sponsorship of prominent signature events in all three states. The Eversource Hartford Marathon resulted in $14 million in increased economic development in Connecticut, while the Eversource Walk for Kids for Boston Children's Hospital exemplifies our decade-long commitment to patient care, adding to the cumulative millions of dollars our employees have raised to support critical research and community health programs. Eversource also made a deep impact with event sponsorships in New Hampshire and the volunteering of our employees at 140 events across our states last year.

I want to thank the 8,000 women and men of Eversource for everything they do to help us serve our customers and our communities. In a time of rapid change and opportunity, we continue to work tirelessly to become the nation’s best energy company.






# 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, 2017

or

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ___ to ___

Commission
File Number
Registrant; State of Incorporation;
Address; and Telephone Number
I.R.S. Employer
Identification No.

1-5324
EVERSOURCE ENERGY
(a Massachusetts voluntary association)
300 Cadwell Drive
Springfield, Massachusetts 01104
Telephone: (800) 286-5000
04-2147929

0-00404
THE CONNECTICUT LIGHT AND POWER COMPANY
(a Connecticut corporation)
107 Selden Street
Berlin, Connecticut 06037-1616
Telephone: (800) 286-5000
06-0303850

1-02301
NSTAR ELECTRIC COMPANY
(a Massachusetts corporation)
800 Boylston Street
Boston, Massachusetts 02199
Telephone: (800) 286-5000
04-1278810

1-6392
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
02-0181050



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

<table><tr><td>Registrant</td><td>Title of Each Class</td><td>Name of Each Exchange on Which Registered</td></tr><tr><td>Eversource Energy</td><td>Common Shares, $5.00 par value</td><td>New York Stock Exchange, Inc.</td></tr></table>

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

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

<table><tr><td>Yes</td><td>No</td></tr><tr><td>☒</td><td>☐</td></tr></table>

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

<table><tr><td>Yes</td><td>No</td></tr><tr><td>☐</td><td>☒</td></tr></table>

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.

<table><tr><td>Yes</td><td>No</td></tr><tr><td>☒</td><td>☐</td></tr></table>

Indicate by check mark whether the registrants have submitted electronically and posted on its corporate Web sites, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrants were required to submit and post such files).

<table><tr><td>Yes</td><td>No</td></tr><tr><td>☒</td><td>☐</td></tr></table>



Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrants' knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. □

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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. (Check one):

<table><tr><td></td><td>Large accelerated filer</td><td>Accelerated filer</td><td>Non-accelerated filer</td><td>Smaller reporting company</td><td>Emerging growth company</td></tr><tr><td>Eversource Energy</td><td>☒</td><td>☐</td><td>☐</td><td>☐</td><td>☐</td></tr><tr><td>The Connecticut Light and Power Company</td><td>☐</td><td>☐</td><td>☒</td><td>☐</td><td>☐</td></tr><tr><td>NSTAR Electric Company</td><td>☐</td><td>☐</td><td>☒</td><td>☐</td><td>□</td></tr><tr><td>Public Service Company of New Hampshire</td><td>☐</td><td>☐</td><td>☒</td><td>☐</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 Exchange 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, 2017) was $19,210,596,737 based on a closing market price of $60.71 per share for the 316,432,165 common shares outstanding held by non-affiliates on June 30, 2017.

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

<table><tr><td>Company - Class of Stock</td><td>Outstanding as of January 31, 2018</td></tr><tr><td>Eversource Energy</td><td></td></tr><tr><td>Common Shares, $5.00 par value</td><td>316,885,808 shares</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.



[This page left blank intentionally.]



## 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 and other subsidiaries, which primarily includes our unregulated businesses, HWP Company, The Rocky River Realty Company (a real estate subsidiary), and the consolidated operations of CYAPC and YAEC, and Aquarion&#x27;s water business from the date of acquisition on December 4, 2017 through December 31, 2017</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>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 (formerly known as Macquarie Utilities Inc)</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>A project being developed jointly by Eversource and Denmark-based Ørsted (formerly known as DONG Fenerev) to construct an offshore wind farm off the coast of Massachusetts</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>Electric and Natural Gas Companies</td><td>The Eversource electric and natural gas 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, the generation facilities of PSNH, 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>Access Northeast</td><td>A project being developed jointly by Eversource, Enbridge, Inc. (&quot;Enbridge&quot;), and National Grid plc (&quot;National Grid&quot;) through Algonquin Gas Transmission, LLC to bring needed additional natural gas pipeline and storage capacity to New England.</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>AOCL</td><td>Accumulated Other Comprehensive Loss</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>Clean Air Project</td><td>The construction of a wet flue gas desulphurization system, known as &quot;scrubber technology,&quot; to reduce mercury emissions of the Merrimack coal-fired generation station in Bow, New Hampshire</td></tr><tr><td>CO₂</td><td>Carbon dioxide</td></tr><tr><td>CPSL</td><td>Capital Projects Scheduling List</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></table>



<table><tr><td>EPS</td><td>Earnings Per Share</td></tr><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>ESPP</td><td>Employee Share Purchase Plan</td></tr><tr><td>Eversource 2016 Form 10-K</td><td>The Eversource Energy and Subsidiaries 2016 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>kWh</td><td>Kilowatt-Hours (the basic unit of electricity energy equal to one kilowatt of power supplied for one hour)</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>MMcf</td><td>Million cubic feet</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>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>NOx</td><td>Nitrogen oxides</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 that provides certain retiree benefits, primarily medical, dental and life insurance</td></tr><tr><td>PCRBs</td><td>Pollution Control Revenue Bonds</td></tr><tr><td>Pension Plan</td><td>Single uniform noncontributory defined benefit retirement plan</td></tr><tr><td>PPA</td><td>Pension Protection Act</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 and generation business segment excluding the wholesale transmission segment</td></tr><tr><td>RNS</td><td>Regional Network Service</td></tr><tr><td>ROE</td><td>Return on Equity</td></tr><tr><td>RRB</td><td>Rate Reduction Bond or Rate Reduction Certificate</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>SIP</td><td>Simplified Incentive Plan</td></tr><tr><td>SO2</td><td>Sulfur dioxide</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></table>



# EVERSOURCE ENERGY AND SUBSIDIARIES
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY

## 2017 FORM 10-K ANNUAL REPORT

## TABLE OF CONTENTS

PART I
Item 1. Business 2
Item 1A. Risk Factors 16
Item 1B. Unresolved Staff Comments 19
Item 2. Properties 20
Item 3. Legal Proceedings 22
Item 4. Mine Safety Disclosures 23
PART II
Item 5. Market for the Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities 26
Item 6. Selected Consolidated Financial Data 28
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations 29
Item 7A. Quantitative and Qualitative Disclosures about Market Risk 53
Item 8. Financial Statements and Supplementary Data 54
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure 108
Item 9A. Controls and Procedures 108
Item 9B. Other Information 108
PART III
Item 10. Directors, Executive Officers and Corporate Governance 109
Item 11. Executive Compensation 109
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters 109
Item 13. Certain Relationships and Related Transactions, and Director Independence 110
Item 14. Principal Accountant Fees and Services 110
PART IV
Item 15. Exhibits and Financial Statement Schedules 111
Item 16. Form 10-K Summary 111
Signatures 112



# EVERSOURCE ENERGY AND SUBSIDIARIES
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY

# 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:

• cyber breaches and other disruptions to our information technology system that may compromise the confidentiality of our proprietary information and the personal information of our customers.

• acts of war, terrorism or grid disturbances that may disrupt our transmission and distribution systems,

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

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

• changes in business conditions, which could include disruptive technology related to our current or future business model,

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

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

• changes in laws, regulations or regulatory policy,

• 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,

• developments in legal or public policy doctrines,

• technological developments and alternative energy sources,

• 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 SUBSIDIARY

## 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 and owns generation assets used to serve customers;

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

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

- Aquarion Water Company (Aquarion), a regulated water utility holding company that serves residential, commercial, industrial and fire protection customers through its separate three regulated utilities, AWC-CT, AWC-MA and AWC-NH 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, and are each doing business as Eversource Energy in their respective service territories.

On December 31, 2017, Western Massachusetts Electric Company, a former subsidiary of Eversource Energy, merged with and into NSTAR Electric, with NSTAR Electric as the surviving entity. As a result, NSTAR Electric serves all of Eversource Energy's electric customers in Massachusetts. For purposes of this combined Annual Report on Form 10-K, the financial statements and financial information presented for prior years were retrospectively adjusted as if the merger had occurred on the first day of the earliest period presented. Upon the closing of the merger, all assets, contracts, rights and obligations of Western Massachusetts Electric Company were reflected as part of NSTAR Electric.

On December 4, 2017, Eversource acquired Macquarie Utilities Inc., subsequently renamed Eversource Aquarion Holdings, Inc., and its Aquarion Water Company subsidiaries. Collectively, these water utility companies serve residential, commercial, industrial and fire protection customers in parts of Connecticut, Massachusetts and New Hampshire.

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 recognizes three reportable segments: electric distribution, electric transmission, and natural gas distribution. Eversource Energy's electric distribution segment includes the results of PSNH's generation facilities and NSTAR Electric's solar power facilities. The energy transmission and distribution segments represented substantially all of Eversource Energy's total consolidated revenues for the years ended December 31, 2017, 2016 and 2015. CL&P, NSTAR Electric and PSNH do not report separate business segments.



## ELECTRIC DISTRIBUTION SEGMENT

## General

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, plus the regulated electric generation facilities of PSNH and solar power facilities of NSTAR Electric.

The following table shows the sources of electric franchise retail revenues for Eversource Energy's electric distribution companies, collectively, based on categories of customers:

<table><tr><td>(Thousands of Dollars)</td><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Residential</td><td>$ 3,457,986</td><td>$ 3,448,043</td><td>$ 3,608,155</td></tr><tr><td>Commercial</td><td>2,459,985</td><td>2,465,664</td><td>2,476,686</td></tr><tr><td>Industrial</td><td>330,995</td><td>328,103</td><td>326,564</td></tr><tr><td>Other</td><td>94,091</td><td>139,527</td><td>151,195</td></tr><tr><td>Total Retail Electric Revenues</td><td>$ 6,343,057</td><td>$ 6,381,337</td><td>$ 6,562,600</td></tr></table>

A summary of our distribution companies' retail electric GWh sales volumes and percentage changes for 2017, as compared to 2016, is as follows:

<table><tr><td></td><td>2017</td><td>2016</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>20,496</td><td>21,002</td><td>(2.4)%</td></tr><tr><td>Commercial</td><td>26,570</td><td>27,206</td><td>(2.3)%</td></tr><tr><td>Industrial</td><td>5,180</td><td>5,434</td><td>(4.7)%</td></tr><tr><td>Total</td><td>52,246</td><td>53,642</td><td>(2.6)%</td></tr></table>

Certain Eversource electric, natural gas and water companies, including CL&P and NSTAR Electric (for a portion of its customers), have a regulatory commission approved revenue decoupling mechanism ("decoupled companies"). Distribution revenues are decoupled from customer sales volumes, where applicable, which breaks the relationship between sales volumes and revenues recognized. The decoupled companies reconcile their annual base distribution rate recovery to pre-established levels of baseline distribution delivery service revenues. Any difference between the allowed level of distribution revenue and the actual amount realized is adjusted through rates in a subsequent period.

Retail electric sales volumes at our electric utilities with a traditional rate structure (the eastern region of NSTAR Electric and PSNH) were lower in 2017, as compared to 2016, due primarily to the mild summer weather in 2017, as compared to 2016. Cooling degree days in 2017 were 14.7 percent lower in the Boston metropolitan area and 22.7 percent lower in New Hampshire, as compared to 2016. Sales volumes were positively impacted by improved economic conditions across our service territories, but this trend was offset by lower customer usage driven by the impact of increased customer energy conservation efforts.

CL&P and NSTAR Electric (for its western Massachusetts customer rates) reconcile their annual base distribution rate recovery amounts to their pre-established levels of baseline distribution delivery service revenues of $1.059 billion and $132.4 million, respectively, through December 31, 2017. Effective February 1, 2018, NSTAR Electric, operating entirely under decoupled rates, will reconcile its annual base distribution rate recovery to its new baseline of $974.8 million.

## 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, 2017, CL&P furnished retail franchise electric service to approximately 1.2 million customers in 149 cities and towns in Connecticut, covering an area of 4,400 square miles. CL&P does not own any electric generation facilities.

The following table shows the sources of CL&P's electric franchise retail revenues based on categories of customers:

<table><tr><td rowspan="2">(Thousands of Dollars)</td><td colspan="3">CL&amp;P</td></tr><tr><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Residential</td><td>$ 1,649,294</td><td>$ 1,603,351</td><td>$ 1,641,165</td></tr><tr><td>Commercial</td><td>883,904</td><td>858,965</td><td>841,093</td></tr><tr><td>Industrial</td><td>144,672</td><td>139,556</td><td>129,544</td></tr><tr><td>Other</td><td>29,144</td><td>47,672</td><td>62,704</td></tr><tr><td>Total Retail Electric Revenues</td><td>$ 2,707,014</td><td>$ 2,649,544</td><td>$ 2,674,506</td></tr></table>

A summary of CL&P's retail electric GWh sales volumes and percentage changes for 2017, as compared to 2016, is as follows:

<table><tr><td></td><td>2017</td><td>2016</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>9,642</td><td>9,907</td><td>(2.7)%</td></tr><tr><td>Commercial</td><td>9,161</td><td>9,461</td><td>(3.2)%</td></tr><tr><td>Industrial</td><td>2,146</td><td>2,249</td><td>(4.6)%</td></tr><tr><td>Total</td><td>20,949</td><td>21,617</td><td>(3.1)%</td></tr></table>



## 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 semi-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 the amounts recovered from customers, on an annual basis, to the distribution revenue requirement approved by the PURA in its last rate case, which currently is an annual amount of $1.059 billion.

- 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 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 also recovers costs associated with CL&P's system resiliency program. The FMCC is adjusted periodically and reconciled semi-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.

- 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 and a program that compensates municipalities for lost property tax revenues due to decreased values of generating facilities caused by electric industry restructuring. The SBC is reconciled annually to actual costs incurred and reviewed by the PURA, with any difference refunded to, or recovered from, customers.

- A Clean Energy Fund charge, which is used to promote investment in renewable energy sources. Amounts collected by this charge are deposited into the Clean Energy Fund and administered by the Clean Energy Finance and Investment Authority. The Clean Energy Fund charge is set by statute and is currently 0.1 cent per kWh.

- A conservation charge, comprised of a statutory rate established to implement cost-effective energy conservation programs and market transformation initiatives, plus a conservation adjustment mechanism charge to recover the residual energy efficiency spending associated with the expanded energy efficiency costs directed by the Comprehensive Energy Strategy Plan for Connecticut.

As required by regulation, CL&P, jointly with UI, entered into the following contracts whereby UI will share 20 percent and CL&P will share 80 percent of the costs and benefits (CL&P's portion of these costs are either recovered from, or refunded to, customers through the FMCC):

- Four capacity CfDs (totaling approximately 787 MW of capacity) with three electric generation units and one demand response project, which extend through 2026 and have terms of up to 15 years beginning in 2009. The capacity CfDs obligate both CL&P and UI to make or receive payments on a monthly basis to or from the project and generation owners based on the difference between a contractually set capacity price and the capacity market prices that the project and generation owners receive in the ISO-NE capacity markets.

- Three peaker CfDs (totaling approximately 500 MW of peaking capacity) with three peaking generation units. The three peaker CfDs pay the generation owners the difference between capacity, forward reserve and energy market revenues and a cost-of-service payment stream for 30 years beginning in 2008 (including costs of plant operation and the prices that the generation owners receive for capacity and other products in the ISO-NE markets).

Distribution Rates: On April 20, 2017, PURA approved the joint request of CL&P, the Connecticut Office of Consumer Counsel ("OCC") and the Connecticut Attorney General to amend the deadline to establish new electric distribution rates in the 2012 Connecticut merger settlement



agreement from "no later than December 1, 2017" to "no later than July 1, 2018." On November 22, 2017, CL&P filed its application with PURA, which sought a rate increase of $255.8 million, $45.0 million and $36.0 million effective May 2018, 2019, and 2020, respectively. On December 15, 2017, CL&P, the Prosecutorial Unit of PURA, and the OCC reached a settlement in principle.

On January 11, 2018, CL&P filed the distribution rate case settlement agreement for approval by PURA, which included, among other things, rate increases of $97.1 million, $32.7 million and $24.7 million, effective May 1, 2018, 2019, and 2020, respectively, an authorized regulatory ROE of 9.25 percent, 53 percent common equity in CL&P's capital structure, and a new capital tracker through 2020 for capital additions, system resiliency, and grid modernization. The rate increases associated with the settlement agreement will be reduced by the impact of the decrease in the federal corporate income tax rate, as part of the "Tax Cuts and Jobs Act", which we currently estimate to average approximately $45 million to $50 million per year, while amounts related to ADIT will be addressed in a separate manner. We expect to receive final approval from PURA in the second quarter of 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. CL&P continues to supply approximately 42 percent of its customer load at SS or LRS rates while the other 58 percent of its customer load has migrated to competitive energy suppliers. 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 2018. For the second half of 2018, CL&P has 60 percent of its SS load under full requirements contracts, and intends to purchase an additional 40 percent of full requirements. None of the SS load for 2019 has been procured. CL&P has full requirements contracts in place for its LRS loads through June 2018 and intends to purchase 100 percent of full requirements for the remainder of 2018.

## ELECTRIC DISTRIBUTION – MASSACHUSETTS

## NSTAR ELECTRIC COMPANY

NSTAR Electric's distribution business consists primarily of the purchase, delivery and sale of electricity to residential, commercial and industrial customers within its franchise service territory. As of December 31, 2017, NSTAR Electric furnished retail franchise electric service to approximately 1.4 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 used to supply customers and purchases its energy requirements from competitive energy suppliers.

On December 29, 2016, the DPU approved NSTAR Electric's application to develop 62 MW of new solar power facilities. Currently, NSTAR Electric owns 8 MW of solar power facilities on sites in Pittsfield, Springfield, and East Springfield, Massachusetts that were completed from 2010 through 2014. We expect development of the new facilities to be completed in 2018. Similar to NSTAR Electric's current practice on the existing 8MW of solar power facilities, we expect that NSTAR Electric will sell energy from the new facilities into the ISO-NE market. We estimate our investment in these new facilities will be approximately $180 million.

The following table shows the sources of the electric franchise retail revenues of NSTAR Electric based on categories of customers:

<table><tr><td rowspan="2">(Thousands of Dollars)</td><td colspan="3">NSTAR Electric</td></tr><tr><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Residential</td><td>$ 1,271,253</td><td>$ 1,322,778</td><td>$ 1,461,184</td></tr><tr><td>Commercial</td><td>1,278,739</td><td>1,310,743</td><td>1,322,674</td></tr><tr><td>Industrial</td><td>113,952</td><td>117,683</td><td>120,106</td></tr><tr><td>Other</td><td>45,347</td><td>54,666</td><td>53,388</td></tr><tr><td>Total Retail Electric Revenues</td><td>$ 2,709,291</td><td>$ 2,805,870</td><td>$ 2,957,352</td></tr></table>

A summary of NSTAR Electric's retail electric GWh sales volumes and percentage changes for 2017, as compared to 2016, is as follows:

<table><tr><td rowspan="2"></td><td colspan="3">NSTAR Electric</td></tr><tr><td>2017</td><td>2016</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>7,721</td><td>7,959</td><td>(3.0)%</td></tr><tr><td>Commercial</td><td>14,127</td><td>14,404</td><td>(1.9)%</td></tr><tr><td>Industrial</td><td>1,691</td><td>1,802</td><td>(6.2)%</td></tr><tr><td>Total</td><td>23,539</td><td>24,165</td><td>(2.6)%</td></tr></table>

In 2017 and 2016, NSTAR Electric operated under two different rate structures based on its service territory geography. For customers in eastern Massachusetts, including metropolitan Boston, Cape Cod and Martha's Vineyard, NSTAR Electric operated using Traditional rates. For customers in western Massachusetts, including the metropolitan Springfield region, NSTAR Electric operated using Decoupled rates. Effective February 1, 2018, all of NSTAR Electric's distribution revenues were decoupled as a result of the DPU-approved rate decision. See "Regulatory Developments and Rate Matters - Massachusetts - NSTAR Electric Distribution Rate Case Decision" in the accompanying Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.



## 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). 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, effective 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.

NSTAR Electric continues to supply approximately 50 percent of its Residential customer load, 41 percent of its Small Commercial and Industrial (C&I) customer load, and 9 percent of its Large C&I customer load at basic service rates. The remainder of its customer load is 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.

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, including costs related to charge-offs of uncollectible energy costs from customers. 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. 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 power to its destination, as well as ongoing operating costs.

- A revenue decoupling adjustment that reconciles distribution revenue, on an annual basis, to the amount of distribution revenue approved by the DPU. During 2017 only the western Massachusetts customer rates, including the metropolitan Springfield region, were decoupled, which resulted in allowed distribution revenues of approximately $132.4 million. Effective February 1, 2018, NSTAR Electric is allowed to collect distribution revenues of $974.8 million annually, which covers its entire service territory.

- 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.

- 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.

- 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.

- Reconciling adjustment charges that recover certain DPU-approved costs, including pension and PBOP benefits, low income customer discounts, lost revenue and credits associated with net-metering facilities installed by customers, costs associated with the solar power facilities, storms, long-term renewable contracts and energy efficiency programs.

As required by regulation, NSTAR Electric, along with two other Massachusetts electric utilities, signed long-term commitments to purchase a combined estimated generating capacity of approximately 334 MW of wind power from two wind farms in Maine over 15 years. One wind farm began operating in late 2015, and the other wind farm began operating in late 2016. In addition, NSTAR Electric previously signed a long-term commitment to purchase an estimated generating capacity of approximately 37.5 MW of wind power from a wind farm in Maine over 15 years that began operating in 2016.

Distribution Rates: On November 30, 2017, the DPU issued its decision in the NSTAR Electric distribution rate case, which approved an annual distribution rate increase of $37 million, with rates effective February 1, 2018. On January 3, 2018, NSTAR Electric filed a motion to reflect a revenue requirement reduction of $56 million (due to the decrease in the federal corporate income tax rate, as part of the "Tax Cuts and Jobs Act"), resulting in an annual net decrease in rates of $19 million.



In addition to its decision regarding rates, the DPU approved an authorized regulatory ROE of 10 percent, the establishment of a revenue decoupling rate mechanism for the portion of the NSTAR Electric business that did not previously have a decoupling mechanism, and the implementation of an inflation-based adjustment mechanism with a five-year stay-out until January 1, 2023.

Among other items, the DPU approved the recovery of previously expensed merger-related costs over a 10-year period and the recovery of previously deferred storm costs with carrying charges at the prime rate, but disallowed certain property taxes. The rate case decision resulted in the recognition of an aggregate $44.1 million pre-tax benefit recorded in 2017.

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 2017 performance as the company achieved results at or above target for all of its SQ metrics in 2017.

## Sources and Availability of Electric Power Supply

As noted above, NSTAR Electric does not own any generation assets (other than solar power facilities), and it 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 50 percent of its residential and small commercial and industrial customers twice per year for twelve month terms. NSTAR Electric enters into supply contracts for basic service for 100 percent of large commercial and industrial customers every three months.

## ELECTRIC DISTRIBUTION – NEW HAMPSHIRE

## PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE

PSNH's distribution business consists primarily of the generation, delivery and sale of electricity to its residential, commercial and industrial customers. As of December 31, 2017, PSNH furnished retail franchise electric service to approximately 515,000 retail customers in 211 cities and towns in New Hampshire, covering an area of approximately 5,630 square miles. As of December 31, 2017, PSNH owned and operated approximately 1,200 MW of coal-, natural gas-, oil-fired, and hydro electricity generation facilities. PSNH's distribution business included the activities of its generation facilities.

On October 11, 2017, PSNH entered into a Purchase and Sale Agreement for the sale of its thermal generation facilities and a separate Purchase and Sale Agreement for the sale of its hydroelectric generation facilities. On January 10, 2018, PSNH completed the sale of its thermal generation facilities. The thermal generation facilities included approximately 1,100 MW of coal, natural gas, biomass and oil-fired electricity generation facilities. The sale of the hydroelectric generation facilities is targeted to close by the end of the first quarter of 2018. For further information, see "Generation Divestiture" below.

The following table shows the sources of PSNH's electric franchise retail revenues based on categories of customers:

<table><tr><td rowspan="2">(Thousands of Dollars)</td><td colspan="3">PSNH</td></tr><tr><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Residential</td><td>$ 537,439</td><td>$ 521,914</td><td>$ 505,806</td></tr><tr><td>Commercial</td><td>297,342</td><td>295,956</td><td>312,918</td></tr><tr><td>Industrial</td><td>72,371</td><td>70,864</td><td>76,914</td></tr><tr><td>Other</td><td>19,600</td><td>37,188</td><td>35,103</td></tr><tr><td>Total Retail Electric Revenues</td><td>$ 926,752</td><td>$ 925,922</td><td>$ 930,741</td></tr></table>

A summary of PSNH's retail electric GWh sales volumes and percentage changes for 2017, as compared to 2016, is as follows:

<table><tr><td></td><td>2017</td><td>2016</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>3,134</td><td>3,136</td><td>(0.1)%</td></tr><tr><td>Commercial</td><td>3,282</td><td>3,342</td><td>(1.8)%</td></tr><tr><td>Industrial</td><td>1,342</td><td>1,382</td><td>(2.9)%</td></tr><tr><td>Total</td><td>7,758</td><td>7,860</td><td>(1.3)%</td></tr></table>

## 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. Prior to the Generation Divestiture, PSNH provided default energy service under its ES rate for those customers who did not choose a competitive energy supplier. At the end of 2017, approximately 26 percent of all of PSNH's customers (approximately 56 percent of load) were taking service from competitive energy suppliers, compared to 25 percent of customers (approximately 56 percent of load) at the end of 2016.



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

- A default energy service charge 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. Through March 31, 2018, the default energy service charge recovers the costs of PSNH's generation, as well as purchased power, and includes an allowed ROE of 9.81 percent. Effective April 1, 2018, as a result of the divestiture of its generation assets, PSNH will obtain power for retail customers who have not chosen a competitive supplier through a periodic market solicitation with the rate set to recover the cost of that power and statutorily mandated renewable portfolio standard costs. Effective April 1, 2018, any remaining costs from ownership of generation will be recovered as part of the SCRC described below.

- A distribution charge, which includes an energy and/or demand-based charge 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. This 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 and other long-term investments and obligations. The stranded costs associated with the sale of the generation facilities, which are targeted to be sold in their entirety by the end of the first quarter of 2018, will be recovered in the SCRC rate charged to PSNH customers.

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

• An electricity consumption tax, which is a state mandated tax on electric energy consumption.

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

In New Hampshire, PSNH distribution rates were 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.

## Generation Divestiture

In June 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement, under the terms of which PSNH agreed to divest its generation assets, subject to NHPUC approval. The NHPUC approval for this agreement, as well as NHPUC approval of the final divestiture plan and auction process, were received in the second half of 2016. In October 2017, PSNH entered into two Purchase and Sale Agreements ("Agreements") to sell its thermal and hydroelectric generation assets to private investors at purchase prices of $175 million and $83 million, respectively, subject to adjustments as set forth in the Agreements. The NHPUC approved the Agreements in late November 2017.

On January 10, 2018, PSNH completed the sale of its thermal generation facilities. In accordance with the Purchase and Sale 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, resulting in net proceeds of $134.1 million. We are targeting for PSNH to complete the sale of its hydroelectric generation facilities by the end of the first quarter of 2018 at a sale price of $83 million, subject to adjustment. On January 30, 2018, the NHPUC approved the issuance of rate reduction bonds up to $690 million to recover stranded costs, subject to an audit by the NHPUC Audit Staff. This order is subject to an appeal period of 30 days.

Upon completion of the divestiture, full recovery of PSNH's generation assets and transaction-related costs are expected to occur through a combination of cash flows during the remaining operating period, sales proceeds, and recovery of stranded costs via the issuance of bonds that will be secured by a non-bypassable charge or through recoveries in future rates billed to PSNH's customers.

## Sources and Availability of Electric Power Supply

During 2017, approximately 47 percent of PSNH's load was met through its own generation, long-term power supply provided pursuant to orders of the NHPUC, and contracts with competitive energy suppliers. The remaining 53 percent of PSNH's load was met by short-term (less than one year) purchases and spot purchases in the competitive New England wholesale power market. Included in the above are PSNH's obligations to purchase power from approximately two dozen IPPs, the output of which it either uses to serve its customer load or sells into the ISO-NE market. With the anticipated completion of the divestiture of its own generation facilities in the first quarter of 2018, PSNH will meet its load requirements in 2018 with purchases of energy requirements from competitive sources through requests for proposals issued periodically, consistent with NHPUC regulations.



## ELECTRIC TRANSMISSION SEGMENT

## General

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 Revenues

A summary of Eversource Energy's wholesale transmission revenues is as follows:

<table><tr><td>(Thousands of Dollars)</td><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>CL&amp;P</td><td>$ 609,880</td><td>$ 575,735</td><td>$ 513,025</td></tr><tr><td>NSTAR Electric</td><td>514,151</td><td>483,050</td><td>428,743</td></tr><tr><td>PSNH</td><td>177,821</td><td>151,354</td><td>127,509</td></tr><tr><td>Total Wholesale Transmission Revenues</td><td>$ 1,301,852</td><td>$ 1,210,139</td><td>$ 1,069,277</td></tr></table>

## 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 refunded to, transmission customers.

## FERC Base ROE Complaints

Four separate complaints have been 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, 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 15-month complaint periods arising from the separate complaints. In the fourth complaint, the Complainants challenged the NETOs' base ROE 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 D.C. Circuit Court of Appeals issued a decision on April 14, 2017 vacating and remanding the FERC's decision. For further information, see "FERC Regulatory Issues - FERC ROE Complaints" in the accompanying Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.

## Transmission Projects

During 2017, we were involved in the planning, development and construction of a series of electric transmission projects, including the Greater Hartford Central Connecticut projects and the Greater Boston Reliability Solutions, that will be built within the next five years and that will enhance system reliability and improve capacity. We were also involved in the planning and development of Northern Pass and the Seacoast Reliability Project. On February 1, 2018, the New Hampshire Site Evaluation Committee ("NHSEC") voted to deny Northern Pass' siting application. Consistent with Eversource's and HQ's long-term relationship to bring clean energy into New England, Eversource and HQ continue to support Northern Pass and the many benefits this project will bring to our customers and region. Eversource intends to seek reconsideration of the NHSEC's decision and to review all options for moving this critical clean energy project forward. For further information, 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.

## 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 2017, our estimated transmission rate base was approximately $6 billion, including approximately $2.7 billion at CL&P, $2.5 billion at NSTAR Electric, and $765 million at PSNH.



## NATURAL GAS DISTRIBUTION SEGMENT

NSTAR Gas distributes natural gas to approximately 292,000 customers in 51 communities in central and eastern Massachusetts covering 1,067 square miles, and Yankee Gas distributes natural gas to approximately 232,000 customers in 72 cities and towns in Connecticut covering 2,187 square miles. Total throughput (sales and transportation) in 2017 was approximately 69.4 Bcf for NSTAR Gas and 56.0 Bcf for Yankee Gas. Our natural gas businesses provide firm natural gas sales service to 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, and commercial and industrial customers who choose to purchase natural gas from Eversource Energy's natural gas distribution companies. 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 and additional vaporization capacity.

Yankee Gas owns a 1.2 Bcf LNG facility in Waterbury, Connecticut, which 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. Predominantly all residential customers in the NSTAR Gas service territory buy natural gas supply and delivery from NSTAR Gas while all customers may choose their natural gas suppliers. 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. NSTAR Gas offers firm transportation service to all customers who purchase natural gas from sources other than NSTAR Gas while Yankee Gas offers firm transportation service to its commercial and industrial customers who purchase natural gas from sources other than Yankee Gas. In addition, both natural gas distribution companies offer interruptible transportation and interruptible natural gas sales service to those high volume commercial and industrial customers, generally during the colder months, that have the capability to switch from natural gas to an alternative fuel on short notice, for whom NSTAR Gas and Yankee Gas can interrupt service during peak demand periods or at any other time to maintain distribution system integrity.

The following table shows the sources of the total Eversource Energy natural gas franchise retail revenues based on categories of customers:

<table><tr><td>(Thousands of Dollars)</td><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Residential</td><td>$ 500,229</td><td>$ 446,052</td><td>$ 497,873</td></tr><tr><td>Commercial</td><td>312,034</td><td>279,001</td><td>327,439</td></tr><tr><td>Industrial</td><td>90,024</td><td>80,093</td><td>93,378</td></tr><tr><td>Total Retail Natural Gas Revenues</td><td>$ 902,287</td><td>$ 805,146</td><td>$ 918,690</td></tr></table>

A summary of our firm natural gas sales volumes in million cubic feet and percentage changes for 2017, as compared to 2016, is as follows:

<table><tr><td></td><td>2017</td><td>2016</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>37,421</td><td>35,734</td><td>4.7%</td></tr><tr><td>Commercial</td><td>42,992</td><td>41,895</td><td>2.6%</td></tr><tr><td>Industrial</td><td>20,613</td><td>20,413</td><td>1.0%</td></tr><tr><td>Total</td><td>101,026</td><td>98,042</td><td>3.0%</td></tr><tr><td>Total, Net of Special Contracts (1)</td><td>96,617</td><td>93,346</td><td>3.5%</td></tr></table>

(1) Special contracts are unique to the 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.

Our firm natural gas sales volumes are subject to many of the same influences as our retail electric sales volumes. In addition, they have benefited from customer growth in both of our natural gas distribution companies. Consolidated firm natural gas sales volumes were higher in 2017, as compared to 2016, due primarily to colder winter weather in the fourth quarter of 2017, as compared to 2016. Heating degree days in 2017 were 2.5 percent higher in Connecticut, as compared to 2016. Sales volumes were also positively impacted by improved economic conditions across our natural gas service territories.

For NSTAR Gas, the DPU approved a distribution revenue decoupling mechanism effective January 1, 2016. Natural gas distribution revenues are decoupled from their customer sales volumes, where applicable, which breaks the relationship between sales volumes and revenues recognized. As a result, fluctuations in natural gas sales volumes in Massachusetts do not impact earnings.

## 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 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. 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, and costs associated with low income customers. The LDAC is reset annually and provides for the recovery of certain costs applicable to both sales and transportation customers.

- Purchased Gas Adjustment ("PGA") clause, which 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.

- 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.

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 purchase 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 2017 performance as it achieved results at or above target for all of its SQ metrics in 2017.

NSTAR Gas distribution rates were set in its 2015 DPU approved rate case, which included an annualized base rate increase of $15.8 million, plus other increases of approximately $11.5 million, mostly relating to recovery of pension and PBOP expenses and the Hopkinton Gas Service Agreement, effective January 1, 2016. In the order, the DPU also approved an authorized regulatory ROE of 9.8 percent, the establishment of a revenue decoupling mechanism, the recovery of certain bad debt expenses, and a 52.1 percent equity component of its capital structure.

Yankee Gas' last rate case proceeding was in 2011, which approved an allowed ROE of 8.83 percent and allowed for a substantial increase in annual spending for bare steel and cast iron pipeline replacement. In 2015, Yankee Gas entered into a settlement agreement with the PURA staff pursuant to which Yankee Gas provided a $1.5 million rate credit to firm customers beginning in December 2015, and established an earnings sharing mechanism whereby Yankee Gas and its customers will share equally in any earnings exceeding a 9.5 percent ROE in a twelve month period commencing with the period from April 1, 2015 through March 31, 2016. As of December 31, 2017, Yankee Gas had not triggered any of the earnings sharing thresholds.

## Massachusetts Natural Gas Replacement and Expansion

On July 7, 2014, Massachusetts enacted "An Act Relative to Natural Gas Leaks" (the "Act"). The Act established a uniform natural gas leak classification standard for all Massachusetts natural gas utilities and a program that accelerates the replacement of aging natural gas infrastructure. The program enabled companies, including NSTAR Gas, to better manage the scheduling and costs of replacement. The Act called for the DPU to authorize natural gas utilities to design and offer programs to customers that will increase the availability, affordability and feasibility of natural gas service for new customers.

In October 2014, pursuant to the Act, NSTAR Gas filed the Gas System Enhancement Program ("GSEP") with the DPU. NSTAR Gas' program accelerates the replacement of certain natural gas distribution facilities in the system to within 25 years. The GSEP includes a new tariff effective January 1, 2016 that provides NSTAR Gas an opportunity to collect the costs for the program on an annual basis through a newly designed reconciling factor. On April 30, 2015, the DPU approved the GSEP. We expect capital expenditures of approximately $374.4 million for the period 2016 through 2020 for the GSEP.

## Connecticut Natural Gas Expansion Plan

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. The Expansion Plan described how Yankee Gas expects to add approximately 82,000 new natural gas heating customers over a 10-year period. Yankee Gas estimates that its portion of the Expansion Plan will cost approximately $700 million over 10 years. 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. On November 30, 2016, Yankee Gas received PURA approval of its initial 2014 System Expansion Reconciliation as well as its 2015 Reconciliation after a combined review of the reconciliations by PURA. Yankee Gas filed its 2016 System Expansion Reconciliation in March 2017, which was approved by PURA on September 13, 2017.



## 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 gas from major 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 portfolio management contract with a term of one year. In addition to the firm transportation and natural gas storage supplies mentioned above, NSTAR Gas utilizes contracts for underground storage and LNG facilities to meet its winter peaking demands. The LNG facilities, described below, 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 the New York and Pennsylvania regions. 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. A portion of the storage of natural gas supply for NSTAR Gas during the winter heating season is provided by Hopkinton LNG Corp., which owns an 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 that include additional storage capacity of 0.5 Bcf and additional vaporization capacity.

The PURA requires that Yankee Gas 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' on-system stored LNG and underground storage supplies help 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 gas from major 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, NSTAR Gas and Yankee Gas each believes that participation in planned and anticipated pipeline and storage expansion projects will be required in order for it to meet current and future sales growth opportunities.

## WATER BUSINESS

Eversource Water Ventures, Inc., a Connecticut corporation, through its wholly-owned subsidiary, Eversource Aquarion Holdings, Inc. (Aquarion), operates 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 226,000 residential, commercial, industrial, municipal and fire protection and other customers, in 59 towns and cities in Connecticut, Massachusetts and New Hampshire. As of December 31, 2017, approximately 87 percent of Aquarion’s customers were based in Connecticut.

For the period from December 4, 2017, the date Aquarion was acquired by Eversource, through December 31, 2017, water franchise retail revenues based on categories of customers for residential, commercial, municipal and fire protection, industrial and other totaled $9.9 million, $2.3 million, $2.5 million, $0.2 million and $1.0 million, respectively.

## 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.

- 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.

- The water infrastructure conservation adjustment (“WICA”) charge, which is applied between rate case proceedings and seeks recovery of allowed costs associated with WICA-eligible capital projects placed in-service. The WICA is updated semiannually in Connecticut and annually in New Hampshire.

- Treatment plant surcharges, which are a series of three surcharges in Massachusetts (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 98 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 PROJECT

Bay State Wind is a proposed offshore wind project being jointly developed by Eversource and Denmark-based Ørsted. Bay State Wind will be located in a 300-square-mile area approximately 25 miles off the coast of Massachusetts that has the ultimate potential to generate more than 2,000 MW of clean, renewable energy. Eversource and Ørsted each hold a 50 percent ownership interest in Bay State Wind.

For more information regarding the clean energy legislation, see "Regulatory Developments and Rate Matters – Massachusetts – Massachusetts RFPs" 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 approximately $10.8 billion from 2018 through 2021, of which we expect approximately $5.7 billion to be in our electric and natural gas distribution segments, approximately $4.1 billion to be in our electric transmission segment and $0.4 billion to be in our water utility business. We also project to invest approximately $0.5 billion in information technology and facilities upgrades and enhancements. These projections do not include any expected investments related to Bay State Wind.

## FINANCING

Our credit facilities and indentures require that Eversource parent and certain of its subsidiaries, including CL&P, NSTAR Electric, PSNH, NSTAR Gas, and 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, 2017, $961.0 million of Eversource's long-term debt, including $450.0 million, $300.0 million, $110.0 million, $100.0 million and $1.0 million for Eversource parent, CL&P, PSNH, Yankee Gas and Aquarion, respectively, will be paid 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 generation facilities and are now engaged in the long-term storage of their spent nuclear fuel. The Yankee Companies have completed collection of their decommissioning and closure costs through the proceeds from the spent nuclear fuel litigation against the DOE and has refunded amounts to its member companies. These proceeds were used by the Yankee Companies to offset the decommissioning and closure cost amounts due from their member companies or to decrease the wholesale FERC-approved rates charged under power purchase agreements with CL&P, NSTAR Electric and PSNH and several other New England utilities. The decommissioning rates charged by the Yankee Companies have been reduced to zero. CL&P, NSTAR Electric and PSNH can recover these costs from, or refund proceeds to, their customers through state regulatory commission-approved retail rates.

We consolidate the assets and obligations of CYAPC and YAEC on our consolidated balance sheet because we own more than 50 percent 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.



## Water Quality Requirements

The Clean Water Act requires every "point source" discharger of pollutants into navigable waters to obtain a National Pollutant Discharge Elimination System ("NPDES") permit from the EPA or state environmental agency specifying the allowable quantity and characteristics of its effluent. States may also require additional permits for discharges into state waters.

## Air Quality Requirements

The Clean Air Act Amendments ("CAAA"), as well as New Hampshire law, impose stringent requirements on emissions of  \( SO_{2} \)  and  \( NO_{x} \)  for the purpose of controlling acid rain and ground level ozone. In addition, the CAAA address the control of toxic air pollutants. Requirements for the installation of continuous emissions monitors and expanded permitting provisions also are included. Following the completion of the sale of PSNH's thermal generation facilities on January 10, 2018, we no longer own facilities subject to the provisions of the CAAA.

## 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 2017, the total RPS obligation was 17.6 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 2017, the total RPS obligation was 22.5 percent and will ultimately reach 28 percent in 2020. 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 2017, the requirement was 22.34 percent, and will ultimately reach 26.1 percent in 2020. 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, 2017, 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 $54.9 million, representing 59 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 gas using coal resulted in fuel oils, hydrocarbons, coal tar, purifier wastes, metals and other waste products that may pose risks to human health and the environment. We currently have partial or full ownership responsibilities at former MGP sites that have a reserve balance of $49.0 million of the total $54.9 million as of December 31, 2017. 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 largest source of greenhouse gas emissions in the U.S. is the electricity generating sector. The EPA has mandated greenhouse gas emission reporting beginning in 2011 for emissions for



certain aspects of our business including stationary combustion, 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 business, both in terms of the generating facilities we own and operate as well as general utility operations. These could include federal "cap and trade" laws, carbon taxes, fuel and energy taxes, or regulations requiring additional capital expenditures at our generating facilities. We expect that any costs of these rules and regulations would be recovered from customers.

Connecticut, New Hampshire and Massachusetts are each members of the Regional Greenhouse Gas Initiative (RGGI), a cooperative effort by nine northeastern and mid-Atlantic states, to develop a regional program for stabilizing and reducing  \( CO_{2} \)  emissions from coal- and oil-fired electric generating plants. Because  \( CO_{2} \)  allowances issued by any participating state are usable across all nine RGGI state programs, the individual state  \( CO_{2} \)  trading programs, in the aggregate, form one regional compliance market for  \( CO_{2} \)  emissions. The third three-year control period took effect on January 1, 2015 and extended through December 31, 2017. In this control period, each regulated power plant must hold  \( CO_{2} \)  allowances equal to 50 percent of its emissions during each of the first two years of the three-year period, and hold  \( CO_{2} \)  allowances equal to 100 percent of its remaining emissions for the three-year control period at the end of the period.

## FERC Hydroelectric Project Licensing

Federal Power Act licenses may be issued for hydroelectric projects for terms of 30 to 50 years as determined by the FERC. Upon the expiration of an existing license, (i) the FERC may issue a new license to the existing licensee, (ii) the United States may take over the project, or (iii) the FERC may issue a new license to a new licensee, upon payment to the existing licensee of the lesser of the fair value or the net investment in the project, plus severance damages, less certain amounts earned by the licensee in excess of a reasonable rate of return.

PSNH currently owns nine hydroelectric generation facilities with a current claimed capability representing winter rates of approximately 71 MW, eight of which are licensed by the FERC under long-term licenses. PSNH and its hydroelectric facilities are subject to conditions set forth in such licenses, the Federal Power Act and related FERC regulations, including provisions related to the condemnation of a project upon payment of just compensation, amortization of project investment from excess project earnings, possible takeover of a project after expiration of its license upon payment of net investment and severance damages and other matters. We are targeting for PSNH to close on the sale of its hydroelectric generation facilities by the end of the first quarter of 2018.

## EMPLOYEES

As of December 31, 2017, Eversource Energy employed a total of 8,084 employees, excluding temporary employees, of which 1,270 were employed by CL&P, 1,922 were employed by NSTAR Electric, and 918 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 11 collective bargaining agreements.

## INTERNET INFORMATION

Our website address is www.eversource.com. We make available through our website a link to the SEC's EDGAR website (http://www.sec.gov/edgar/searchedgar/companysearch.html), at which site Eversource Energy's, CL&P's, NSTAR Electric's and PSNH's Annual Reports on Form 10-K, 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 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, requires certain safeguards to be implemented to deter cyberattacks. These safeguards may not always be effective due to the evolving nature of cyberattacks.

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 or cash flows.

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

Acts of war or terrorism, both threatened and actual, or actual physical attacks that damage our transmission and distribution systems or other assets could negatively impact our ability to transmit or distribute energy, distribute water, 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 blackout due to grid disturbances or disruptions on a neighboring interconnected system. If our assets were physically damaged and were not recovered in a timely manner, it could result in a loss of service to customers and a significant decrease in revenues.

Any such acts of war or terrorism, physical attacks or grid disturbances could result in 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.

Strategic development 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 New England region related to the construction of electric transmission facilities, off-shore wind electric generation facilities, interconnections to generating resources and other investment opportunities. The development of these activities involves numerous risks. Various factors could result in increased costs or result in delays or cancellation of these projects. Risks include regulatory approval processes, new legislation, 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 strategic partners. Should any of these factors result in such delays or cancellations, our financial position, results of operations, and cash flows could be adversely affected or our future growth opportunities may not be realized as anticipated.

As a result of legislative and regulatory changes, the states in which we provide service have implemented new procedures to select for construction new major electric transmission, natural gas pipeline, off-shore 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, other legislative or regulatory actions could result in our projects not being probable of entering the construction phase, it could have a material adverse effect on our future financial position, results of operations and cash flows.

After being selected as the winning bidder in the Massachusetts clean energy RFP in January 2018, on February 1, 2018, the NHSEC voted to deny the siting application for our Northern Pass project. Following the NHSEC's decision, the Massachusetts EDCs, in coordination with the DOER and the independent evaluator, notified NPT that the EDCs will continue contract negotiations, with the option of discontinuing discussions and terminating its conditional selection by March 27, 2018.

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.



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 reasonable operating and capital costs and a reasonable ROE, 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.

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

There is no assurance that the commissions 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 or 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 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. 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 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.

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, including impacts on us or our customers; increased capital expenditure requirements, including those due to environmental regulation; catastrophic events such as fires, explosions, or other similar occurrences; extreme weather conditions beyond equipment and plant design capacity; other unanticipated operations and maintenance expenses and liabilities; 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, conservation measures 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. Customers' increased use of energy efficiency measures, distributed generation and energy storage technology could result in lower demand. Similarly, mandatory water conservation imposed due to drought conditions could result in lower demand for water. Reduced demand for



electricity due to energy efficiency measures and the use of distributed generation, and reduced demand for water due to mandatory or voluntary conservation efforts, to the extent not substantially offset through ratemaking or decoupling mechanisms, could have a material adverse effect on our financial condition, results of operations and cash flows.

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 maintain sensitive customer, employee, financial and system operating information and 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 limited privacy protection liability insurance to cover limited 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 card monitoring of, customers, employees and other persons in the event of a breach of private information. This insurance covers amounts paid to avert, prevent or stop a network attack or the disclosure of personal information, and costs of a qualified forensics firm to determine the cause, source and extent of a network attack or to investigate, examine and analyze our network to find the cause, source and extent of a data breach. While we have implemented measures designed to prevent cyberattacks 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.

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 covered by existing insurance, may exceed such insurance coverage limits, or may not be recoverable in rates. Any such losses may make it difficult for us to obtain insurance at acceptable rates in the future, and may have a material adverse effect on our financial condition, results of operations and cash flows.

Our goodwill is valued and 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, 2017, totaled $4.4 billion. The carrying value of goodwill represents the fair value of an acquired business in excess 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 2017 resulted in a conclusion that our goodwill was not impaired.

Eversource Energy and its utility subsidiaries are exposed to significant reputational risks, which make them 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 the reputations of Eversource Energy and its subsidiaries; may make state legislatures, utility commissions and other regulatory authorities less likely to view them in a favorable light; and may cause them 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. The imposition of any of the foregoing could have a material adverse effect on the business, financial position, results of operations and cash flows of Eversource Energy and each of its utility subsidiaries.

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.



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 who owe us money, have contracted to supply us with energy, coal, or other commodities or services, or who 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.

Costs of compliance with environmental laws and regulations 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, air emissions, water quality, water discharges, and the management of hazardous and solid waste. 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 or cash flows.

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

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 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 and amount of future financings and negatively affect our financial position, results of operations or cash flows. For further information, see Note 9A, "Employee Benefits - Pensions and Postretirement Benefits Other Than Pensions," to the financial statements.

The loss of key personnel or the inability to hire and retain qualified employees 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, 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 cannot predict the impact of these plans on our ability to hire and retain key employees.

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. Additionally, the subsidiary companies could retain their free cash flow to fund their capital expenditures in lieu of receiving equity contributions from Eversource parent. 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, 2017, 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>508</td><td>74</td></tr><tr><td>Transformer capacity (in kVa)</td><td>42,810,000</td><td>17,012,000</td></tr><tr><td>Overhead lines (in circuit miles)</td><td>40,532</td><td>3,947</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 (distribution in circuit miles and transmission in cable miles)</td><td>17,438</td><td>405</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>182</td><td>20</td><td>178</td><td>34</td><td>148</td><td>20</td></tr><tr><td>Transformer capacity (in kVa)</td><td>19,965,000</td><td>3,633,000</td><td>17,535,000</td><td>7,465,000</td><td>5,310,000</td><td>5,914,000</td></tr><tr><td>Overhead lines (in circuit miles)</td><td>16,955</td><td>1,673</td><td>11,404</td><td>1,233</td><td>12,173</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 (distribution in circuit miles and transmission in cable miles)</td><td>6,639</td><td>137</td><td>8,875</td><td>267</td><td>1,924</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>624,472</td><td>289,986</td><td>170,383</td><td>164,103</td></tr><tr><td>Aggregate capacity (in kVa)</td><td>36,140,835</td><td>15,684,715</td><td>13,996,195</td><td>6,459,925</td></tr></table>

## Electric Generating Plants

As of December 31, 2017, PSNH owned the following electric generating plants:

<table><tr><td>Type of Plant</td><td>Number of Units</td><td>Year Installed</td><td>Claimed Capability* (kilowatts)</td></tr><tr><td>Steam Plants</td><td>5</td><td>1952-74</td><td>934,940</td></tr><tr><td>Hydro</td><td>20</td><td>1901-83</td><td>58,951</td></tr><tr><td>Internal Combustion</td><td>5</td><td>1968-70</td><td>101,535</td></tr><tr><td>Biomass</td><td>1</td><td>2006</td><td>42,594</td></tr><tr><td>Total PSNH Generating Plant</td><td>31</td><td></td><td>1,138,020</td></tr></table>

* Claimed capability represents winter ratings as of December 31, 2017. The combined nameplate capacity of the generating plants is approximately 1,200 MW.

On January 10, 2018, Eversource and PSNH completed the sale of PSNH's thermal generation assets, including the steam, internal combustion and biomass units, above. See Note 12, "Assets Held for Sale," in the accompanying Item 8, Financial Statements and Supplementary Data for further information.

As of December 31, 2017, 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>3</td><td>2010-14</td><td>8,000</td></tr></table>

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

CL&P does not own any electric generating plants.

## Natural Gas Distribution System

As of December 31, 2017, Yankee Gas owned 28 active gate stations, 197 district regulator stations, and approximately 3,362 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, 2017, NSTAR Gas owned 21 active gate stations, 166 district regulator stations, and approximately 3,292 miles of natural gas main pipeline. Hopkinton, another subsidiary of Eversource, owns a satellite vaporization plant and above ground storage tanks in Acushnet, MA. In addition, Hopkinton owns a liquefaction and vaporization plant with above ground storage tanks in Hopkinton, MA. 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, 2017, Aquarion owned and operated sources of water supply with a combined yield of approximately 131 million gallons per day; 3,614 miles of transmission and distribution mains; 10 surface water treatment plants; 31 dams; and 106 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, with the exception of municipal-owned utilities, 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.

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. Pursuant to the Massachusetts restructuring legislation, the DPU (then, the Department of Telecommunications and Energy) was required to define service territories for each distribution company, including NSTAR Electric. The DPU subsequently determined that there were advantages to the exclusivity of service territories and issued a report to the Massachusetts Legislature recommending against, in this regard, any changes to the restructuring legislation.

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, with the exception of municipal-owned utilities, 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 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

DOE Phase I Damages - In 1998, the Yankee Companies filed separate complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal by January 31, 1998 pursuant to the terms of the 1983 spent fuel and high-level waste disposal contracts between the Yankee Companies and the DOE ("DOE Phase I Damages"). Phase I covered damages for the years 1998 through 2002. Following multiple appeals and cross-appeals in December 2012, the judgment awarding $39.6 million, $38.3 million and $81.7 million to CYAPC, YAEC and MYAPC, respectively, became final.

In January 2013, the proceeds from the DOE Phase I Damages Claim were received by the Yankee Companies and transferred to each Yankee Company’s respective decommissioning trust.

In June 2013, FERC approved CYAPC, YAEC and MYAPC to reduce rates in their wholesale power contracts through the application of the DOE proceeds for the benefit of customers. Changes to the terms of the wholesale power contracts became effective on July 1, 2013. In accordance with the FERC order, CL&P, NSTAR Electric and PSNH began receiving the benefit of the DOE proceeds, and the benefits have been passed on to customers.

On September 17, 2014, in accordance with the MYAPC refund plan, MYAPC returned a portion of the DOE Phase I Damages proceeds to the member companies, including CL&P, NSTAR Electric and PSNH, in the amount of $3.2 million, $1.9 million and $1.4 million, respectively.



DOE Phase II Damages - In December 2007, the Yankee Companies each filed subsequent lawsuits against the DOE seeking recovery of actual damages incurred related to the alleged failure of the DOE to provide for a permanent facility to store spent nuclear fuel generated in years 2001 through 2008 for CYAPC and YAEC and from 2002 through 2008 for MYAPC ("DOE Phase II Damages"). In November 2013, the court issued a final judgment awarding $126.3 million, $73.3 million, and $35.8 million to CYAPC, YAEC and MYAPC, respectively. On January 14, 2014, the Yankee Companies received a letter from the U.S. Department of Justice stating that the DOE will not appeal the court's final judgment.

In March and April 2014, CYAPC, YAEC and MYAPC received payment of $126.3 million, $73.3 million and $35.8 million, respectively, of the DOE Phase II Damages proceeds and made the required informational filing with FERC in accordance with the process and methodology outlined in the 2013 FERC order. The Yankee Companies returned the DOE Phase II Damages proceeds to the member companies, including CL&P, NSTAR Electric and PSNH, for the benefit of their respective customers, on June 1, 2014. Refunds to CL&P's, NSTAR Electric's and PSNH's customers for these DOE proceeds began in the third quarter of 2014 and all refunds under these proceedings have been disbursed.

DOE Phase III Damages - In August 2013, the Yankee Companies each filed subsequent lawsuits against the DOE seeking recovery of actual damages incurred in the years 2009 through 2012 ("DOE Phase III"). The DOE Phase III trial concluded on July 1, 2015, followed by a post-trial briefing that concluded on October 4, 2015. On March 25, 2016, the court issued its decision and awarded CYAPC, YAEC and MYAPC damages of $32.6 million, $19.6 million and $24.6 million, respectively. In total, the Yankee Companies were awarded $76.8 million of the $77.9 million in damages sought in the DOE Phase III. The decision became final on July 18, 2016, and the Yankee Companies received the awards from the DOE on October 14, 2016. The Yankee Companies received FERC approval of their proposed distribution of certain amounts of the awarded damages proceeds to member companies, including CL&P, NSTAR Electric and PSNH, which CYAPC and MYAPC made in December 2016. MYAPC also refunded $56.5 million from its spent nuclear fuel trust, a portion of which was also refunded to the Eversource utility subsidiaries. In total, Eversource received $26.1 million, of which CL&P, NSTAR Electric and PSNH received $13.6 million, $8.6 million and $3.9 million, respectively. All refunds under these proceedings have been disbursed.

DOE Phase IV Damages - On May 22, 2017, each of the Yankee Companies filed subsequent lawsuits against the DOE in the Court of Federal Claims seeking monetary damages totaling approximately $100 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"). The DOE Phase IV trial is expected to begin in 2018.

## 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 proceedings involving water and air quality requirements, 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.



## EXECUTIVE OFFICERS OF THE REGISTRANT

The following table sets forth the executive officers of Eversource Energy as of February 23, 2018. All of the Company's officers serve terms of one year and until their successors are elected and qualified:

<table><tr><td>Name</td><td>Age</td><td>Title</td></tr><tr><td>James J. Judge</td><td>62</td><td>President and Chief Executive Officer</td></tr><tr><td>Philip J. Lembo</td><td>62</td><td>Executive Vice President and Chief Financial Officer</td></tr><tr><td>Gregory B. Butler</td><td>60</td><td>Executive Vice President and General Counsel</td></tr><tr><td>Christine M. Carmody</td><td>55</td><td>Executive Vice President-Human Resources and Information Technology</td></tr><tr><td>Joseph R. Nolan, Jr.</td><td>54</td><td>Executive Vice President-Customer and Corporate Relations</td></tr><tr><td>Leon J. Olivier</td><td>70</td><td>Executive Vice President-Enterprise Energy Strategy and Business Development</td></tr><tr><td>Werner J. Schweiger</td><td>58</td><td>Executive Vice President and Chief Operating Officer</td></tr><tr><td>Jay S. Buth</td><td>48</td><td>Vice President, Controller and Chief Accounting Officer</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; as a Trustee of Eversource Energy and as Chairman of CL&P, NSTAR Electric and PSNH since May 4, 2016; and as Chairman, President and Chief Executive Officer of Eversource Service and Chairman of NSTAR Gas and Yankee Gas since May 9, 2016. Mr. Judge has served as a Director of CL&P, PSNH, Yankee Gas and Eversource Service since April 10, 2012; and of NSTAR Electric and NSTAR Gas since September 27, 1999. Previously, Mr. Judge served as President and Chief Executive Officer of Eversource Energy from May 4, 2016 until May 3, 2017; as Chairman of WMECO from May 4, 2016 until December 31, 2017; as a Director of WMECO from April 10, 2012 until December 31, 2017; and as Executive Vice President and Chief Financial Officer of Eversource Energy, CL&P, NSTAR Electric, PSNH and WMECO from April 10, 2012 until May 4, 2016; of NSTAR Gas, Yankee Gas and Eversource Service from April 10, 2012 until May 9, 2016. Mr. Judge serves as a director of Analogic Corporation and as chairman of its audit committee. He serves on the Board of Directors of the Edison Electric Institute and the Massachusetts Competitive Partnership. He has also served on the Board of Directors of the United Way of Massachusetts Bay and Merrimack Valley. Mr. Judge has served as Chairman of the Board of Eversource Energy Foundation, Inc. since May 9, 2016; and as a Director since April 10, 2012. He previously served as Treasurer of the Eversource Energy Foundation, Inc. from May 10, 2012 until May 9, 2016. He has served as a Trustee of the NSTAR Foundation since December 12, 1995.

Philip J. Lembo. Mr. Lembo has served as Executive Vice President and Chief Financial Officer of Eversource Energy since May 3, 2017; and of CL&P, NSTAR Electric, NSTAR Gas, PSNH, Yankee Gas and Eversource Service since March 31, 2017. Mr. Lembo has served as a Director of CL&P, NSTAR Electric and PSNH since May 4, 2016; and of NSTAR Gas, Yankee Gas and Eversource Service since May 9, 2016. Mr. Lembo previously served as Executive Vice President and Chief Financial Officer of WMECO from May 3, 2017 until December 31, 2017; as a Director of WMECO from May 4, 2016 until December 31, 2017; as Executive Vice President, Chief Financial Officer and Treasurer of Eversource Energy from August 8, 2016 until May 3, 2017; of CL&P, NSTAR Electric, PSNH, WMECO, NSTAR Gas, Yankee Gas and Eversource Service from August 8, 2016 until March 31, 2017; as Senior Vice President, Chief Financial Officer and Treasurer of Eversource Energy, CL&P, NSTAR Electric, PSNH and WMECO from May 4, 2016 until August 8, 2016; and of NSTAR Gas, Yankee Gas and Eversource Service from May 9, 2016 until August 8, 2016; as Vice President and Treasurer of Eversource Energy, CL&P, PSNH and WMECO from April 10, 2012 until May 4, 2016; and of Yankee Gas and Eversource Service from April 10, 2012 until May 9, 2016. Mr. Lembo served as Vice President and Treasurer of NSTAR Electric and NSTAR Gas from March 29, 2006 until May 4, 2016. Mr. Lembo has served as a Director of Eversource Energy Foundation, Inc. since May 9, 2016. He previously served as Treasurer of Eversource Energy Foundation, Inc. from May 9, 2016 until March 31, 2017. He has served as a Trustee of the NSTAR Foundation since May 9, 2016.

Gregory B. Butler. Mr. Butler has served as Executive Vice President and General Counsel of Eversource Energy, CL&P, NSTAR Electric, NSTAR Gas, PSNH, Yankee Gas and Eversource Service since August 8, 2016. Mr. Butler has served as a Director of NSTAR Electric and NSTAR Gas since April 10, 2012; of Eversource Service since November 27, 2012; and of CL&P, PSNH and Yankee Gas since April 22, 2009. Mr. Butler previously served as Executive Vice President and General Counsel of WMECO from August 8, 2016 until December 31, 2017; as a Director of WMECO from April 22, 2009 until December 31, 2017; as Senior Vice President and General Counsel of Eversource Energy from May 1, 2014 until August 8, 2016; of NSTAR Electric and NSTAR Gas from April 10, 2012 until August 8, 2016; of CL&P, PSNH, WMECO, Yankee Gas and Eversource Service from March 9, 2006 until August 8, 2016; and as Senior Vice President, General Counsel and Secretary of Eversource Energy from April 10, 2012 until May 1, 2014. He has served as a Director of Eversource Energy Foundation, Inc. since December 1, 2002. He has been a Trustee of the NSTAR Foundation since April 10, 2012.

Christine M. Carmody. Ms. Carmody has served as Executive Vice President-Human Resources and Information Technology of Eversource Energy and Eversource Service since August 8, 2016. Ms. Carmody has served as a Director of Eversource Service since November 27, 2012. Previously Ms. Carmody served as Senior Vice President-Human Resources of Eversource Energy from May 4, 2016 until August 8, 2016; of Eversource Service from April 10, 2012 until August 8, 2016; as Senior Vice President-Human Resources of CL&P, PSNH, WMECO and Yankee Gas from November 27, 2012 until September 29, 2014; of NSTAR Electric and NSTAR Gas from August 1, 2008 until September 29, 2014; and as a Director of CL&P, PSNH, WMECO and Yankee Gas from April 10, 2012 until September 29, 2014; and of NSTAR Electric and NSTAR Gas from November 27, 2012 until September 29, 2014. Ms. Carmody has served as a Director of Eversource Energy Foundation, Inc. since April 10, 2012. She has served as a Trustee of the NSTAR Foundation since August 1, 2008.

Joseph R. Nolan, Jr. Mr. Nolan has served as Executive Vice President-Customer and Corporate Relations of Eversource Energy and Eversource Service since August 8, 2016. Mr. Nolan has served as a Director of Eversource Service since November 27, 2012. Previously Mr. Nolan served as Senior Vice President-Corporate Relations of Eversource Energy from May 4, 2016 until August 8, 2016; of Eversource Service from April 10, 2012 to August 8, 2016; of NSTAR Electric and NSTAR Gas from April 10, 2012 until September 29, 2014; and of CL&P, PSNH, WMECO and



Yankee Gas from November 27, 2012 until September 29, 2014. Mr. Nolan previously served as a Director of CL&P, PSNH, WMECO and Yankee Gas from April 10, 2012 until September 29, 2014; and of NSTAR Electric and NSTAR Gas from November 27, 2012 until September 29, 2014. Mr. Nolan has served as a Director of Eversource Energy Foundation, Inc. since April 10, 2012, and as Executive Director of Eversource Energy Foundation, Inc. since October 15, 2013. He has served as a Trustee of the NSTAR Foundation since October 1, 2000.

Leon J. Olivier. Mr. Olivier has served as Executive Vice President-Enterprise Energy Strategy and Business Development of Eversource Energy since September 2, 2014; and of Eversource Service since August 11, 2014. Mr. Olivier has served as a Director of Eversource Service since January 17, 2005. Mr. Olivier previously served as Executive Vice President and Chief Operating Officer of Eversource Energy from May 13, 2008 until September 2, 2014; of Eversource Service from May 13, 2008 until August 11, 2008; as Chief Executive Officer of NSTAR Electric and NSTAR Gas from April 10, 2012 until August 11, 2014; of CL&P, PSNH, WMECO and Yankee Gas from January 15, 2007 until August 11, 2014; and of CL&P from September 10, 2001 until September 29, 2014; as a Director of NSTAR Electric and NSTAR Gas from November 27, 2012 until September 29, 2014; of PSNH, WMECO and Yankee Gas from January 17, 2005 until September 29, 2014; and of CL&P from September 10, 2001 until September 29, 2014. He has served as a Director of Eversource Energy Foundation, Inc. since April 1, 2006. Mr. Olivier has served as a Trustee of the NSTAR Foundation since April 10, 2012.

Werner J. Schweiger. Mr. Schweiger has served as Executive Vice President and Chief Operating Officer of Eversource Energy since September 2, 2014; of Eversource Service since August 11, 2014; and as Chief Executive Officer of CL&P, NSTAR Electric, NSTAR Gas, PSNH and Yankee Gas since August 11, 2014. Mr. Schweiger has served as a Director of Eversource Service, NSTAR Gas and Yankee Gas since September 29, 2014; and of CL&P, PSNH and NSTAR Electric since May 28, 2013. He previously served as Chief Executive Officer of WMECO from August 11, 2014 until December 31, 2017; as a Director of WMECO from May 28, 2013 until December 31, 2017; as President of CL&P from June 2, 2015 until June 27, 2016; as President of NSTAR Gas and Yankee Gas from September 29, 2014 until November 10, 2014; as President-Electric Distribution of Eversource Service from January 16, 2013 until August 11, 2014; as President of NSTAR Electric from April 10, 2012 until January 16, 2013; and as a Director of NSTAR Electric from November 27, 2012 until January 16, 2013. Mr. Schweiger has served as a Director of Eversource Energy Foundation, Inc. since September 29, 2014. He has served as a Trustee of the NSTAR Foundation since September 29, 2014.

Jay S. Buth. Mr. Buth has served as Vice President, Controller and Chief Accounting Officer of Eversource Energy, CL&P, NSTAR Electric, NSTAR Gas, PSNH, Yankee Gas and Eversource Service since April 10, 2012. Previously, Mr. Buth served as Vice President, Controller and Chief Accounting Officer of WMECO from April 10, 2012 until December 31, 2017; and as Vice President-Accounting and Controller of Eversource Energy, CL&P, PSNH, WMECO, Yankee Gas and Eversource Service from June 9, 2009 until April 10, 2012.



## PART II

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

(a) Market Information and (c) Dividends

Eversource. Our common shares are listed on the New York Stock Exchange. The ticker symbol is "ES." The high and low sales prices of our common shares and the dividends declared, for the past two years, by quarter, are shown below.

<table><tr><td>Year</td><td>Quarter</td><td>High</td><td>Low</td><td>Dividends Declared</td></tr><tr><td rowspan="4">2017</td><td>First</td><td>$ 60.36</td><td>$ 54.08</td><td>$ 0.4750</td></tr><tr><td>Second</td><td>63.34</td><td>58.11</td><td>0.4750</td></tr><tr><td>Third</td><td>64.19</td><td>59.55</td><td>0.4750</td></tr><tr><td>Fourth</td><td>66.15</td><td>59.59</td><td>0.4750</td></tr><tr><td>2016</td><td>First</td><td>$ 58.81</td><td>$ 50.01</td><td>$ 0.4450</td></tr><tr><td rowspan="3">2016</td><td>Second</td><td>59.95</td><td>53.90</td><td>0.4450</td></tr><tr><td>Third</td><td>60.44</td><td>53.08</td><td>0.4450</td></tr><tr><td>Fourth</td><td>55.74</td><td>50.56</td><td>0.4450</td></tr></table>

Information with respect to dividend restrictions for us, 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.

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.

Common stock dividends approved and paid to Eversource during the year were as follows:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="2">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td></tr><tr><td>CL&amp;P</td><td>$ 254.8</td><td>$ 199.6</td></tr><tr><td>NSTAR Electric</td><td>272.0</td><td>316.3</td></tr><tr><td>PSNH \( ^{(1)} \)</td><td>23.9</td><td>77.6</td></tr></table>

(1) The 2017 amount does not include $150.0 million of dividends declared but not paid as of December 31, 2017.

(b) Holders

As of January 31, 2018, there were 37,428 registered common shareholders of our company on record. As of the same date, there were a total of 316,885,808 shares issued.

(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.



The performance graph below illustrates a five-year comparison of cumulative total returns based on an initial investment of $100 in 2012 in Eversource Energy common stock, as compared with the S&P 500 Stock Index and the EEI Index for the period 2012 through 2017, assuming all dividends are reinvested.



<table><tr><td></td><td>2012</td><td>2013</td><td>2014</td><td>2015</td><td>2016</td><td>2017</td></tr><tr><td>Eversource Energy</td><td>$100</td><td>$112</td><td>$147</td><td>$145</td><td>$161</td><td>$190</td></tr><tr><td>EEI Index</td><td>$100</td><td>$113</td><td>$146</td><td>$140</td><td>$164</td><td>$184</td></tr><tr><td>S&amp;P 500</td><td>$100</td><td>$132</td><td>$151</td><td>$153</td><td>$171</td><td>$208</td></tr></table>

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

The following table discloses purchases of our common shares made by us or on our behalf for the periods shown below. The common shares purchased consist of open market purchases made by the Company or an independent agent. These share transactions related to shares awarded under the Company's Incentive Plan and Dividend Reinvestment Plan and 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, 2017</td><td>101,737</td><td>60.52</td><td>—</td><td>—</td></tr><tr><td>November 1 - November 30, 2017</td><td>6,411</td><td>64.22</td><td>—</td><td>—</td></tr><tr><td>December 1 - December 31, 2017</td><td>190,873</td><td>62.86</td><td>—</td><td>—</td></tr><tr><td>Total</td><td>299,021</td><td>62.09</td><td>—</td><td>—</td></tr></table>



## 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>2017</td><td>2016</td><td>2015</td><td>2014</td><td>2013</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>$ 23,617,463</td><td>$ 21,350,510</td><td>$ 19,892,441</td><td>$ 18,647,041</td><td>$ 17,576,186</td></tr><tr><td>Total Assets</td><td>36,220,386</td><td>32,053,173</td><td>30,580,309</td><td>29,740,387</td><td>27,760,315</td></tr><tr><td>Common Shareholders&#x27; Equity</td><td>11,086,242</td><td>10,711,734</td><td>10,352,215</td><td>9,976,815</td><td>9,611,528</td></tr><tr><td>Noncontrolling Interest - Preferred Stock of Subsidiaries</td><td>155,570</td><td>155,568</td><td>155,568</td><td>155,568</td><td>155,568</td></tr><tr><td>Long-Term Debt (a)</td><td>12,325,520</td><td>9,603,237</td><td>9,034,457</td><td>8,851,600</td><td>8,310,179</td></tr><tr><td>Obligations Under Capital Leases (a)</td><td>9,898</td><td>8,924</td><td>8,222</td><td>9,434</td><td>10,744</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>$ 7,751,952</td><td>$ 7,639,129</td><td>$ 7,954,827</td><td>$ 7,741,856</td><td>$ 7,301,204</td></tr><tr><td>Net Income</td><td>$ 995,515</td><td>$ 949,821</td><td>$ 886,004</td><td>$ 827,065</td><td>$ 793,689</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>7,682</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 987,996</td><td>$ 942,302</td><td>$ 878,485</td><td>$ 819,546</td><td>$ 786,007</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>$ 3.11</td><td>$ 2.97</td><td>$ 2.77</td><td>$ 2.59</td><td>$ 2.49</td></tr><tr><td>Diluted Earnings Per Common Share</td><td>$ 3.11</td><td>$ 2.96</td><td>$ 2.76</td><td>$ 2.58</td><td>$ 2.49</td></tr><tr><td>Dividends Declared Per Common Share</td><td>$ 1.90</td><td>$ 1.78</td><td>$ 1.67</td><td>$ 1.57</td><td>$ 1.47</td></tr><tr><td>Market Price - Closing (end of year) (b)</td><td>$ 63.18</td><td>$ 55.23</td><td>$ 51.07</td><td>$ 53.52</td><td>$ 42.39</td></tr><tr><td>Book Value Per Common Share (end of year)</td><td>$ 34.98</td><td>$ 33.80</td><td>$ 32.64</td><td>$ 31.47</td><td>$ 30.49</td></tr><tr><td>Tangible Book Value Per Common Share (end of year) (c)</td><td>$ 21.00</td><td>$ 22.70</td><td>$ 21.54</td><td>$ 20.37</td><td>$ 19.32</td></tr><tr><td>Rate of Return Earned on Average Common Equity (%) (d)</td><td>9.1</td><td>9.0</td><td>8.7</td><td>8.4</td><td>8.3</td></tr><tr><td>Market-to-Book Ratio (end of year) (e)</td><td>1.8</td><td>1.6</td><td>1.6</td><td>1.7</td><td>1.4</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 acquisition of Aquarion on December 4, 2017, the classification as held for sale of PSNH's thermal and hydroelectric generating assets as result of generation divestiture, and any accounting changes materially affecting the comparability of the information reflected in the tables above.

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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. 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 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."

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 that is 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. The discussion below also includes non-GAAP financial measures referencing our 2015 earnings and EPS excluding certain integration costs incurred by Eversource parent and our Electric and Natural Gas companies. We use these non-GAAP financial measures to evaluate and to provide details of earnings by business and to more fully compare and explain our 2017, 2016 and 2015 results without including the impact of these items. Due to the nature and significance of these items on Net Income Attributable to Common Shareholders, we believe that the non-GAAP presentation is a meaningful representation of our financial performance and provides additional and useful information to readers of this report in analyzing historical and future performance by 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.

Reconciliations of the non-GAAP financial measures to the most directly comparable GAAP measures of consolidated diluted EPS and Net Income Attributable to Common Shareholders are included under "Financial Condition and Business Analysis – Overview – Consolidated" and "Financial Condition and Business Analysis – Overview – Electric and Natural Gas Companies" in this Management's Discussion and Analysis of Financial Condition and Results of Operations, herein.

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, 2017 throughout this Management's Discussion and Analysis of Financial Condition and Results of Operations.

## Financial Condition and Business Analysis

## Executive Summary

## Results and Future Outlook:

• We earned $988.0 million, or $3.11 per share, in 2017, compared with $942.3 million, or $2.96 per share, in 2016.

- Our electric distribution segment, which includes generation results, earned $497.4 million, or $1.57 per share, in 2017, compared with $462.8 million, or $1.46 per share, in 2016. Our electric transmission segment earned $391.9 million, or $1.23 per share, in 2017, compared with $370.8 million, or $1.16 per share, in 2016. Our natural gas distribution segment earned $74.6 million, or $0.23 per share, in 2017, compared with $77.7 million, or $0.24 per share, in 2016.

- Eversource parent and other companies earned $24.1 million, or $0.08 per share, in 2017, compared with $31.0 million, or $0.10 per share, in 2016.

• We currently project 2018 earnings of between $3.20 per share and $3.30 per share.

## Liquidity:

- Cash flows provided by operating activities totaled $2.0 billion in 2017, compared with $2.2 billion in 2016. Investments in property, plant and equipment totaled $2.3 billion in 2017 and $2.0 billion in 2016. Cash and cash equivalents totaled $38.2 million as of December 31, 2017, compared with $30.3 million as of December 31, 2016.

- In 2017, we issued $2.5 billion of new long-term debt, consisting of $1.2 billion by Eversource parent, $700 million by NSTAR Electric, $525 million by CL&P and $75 million by Yankee Gas. Proceeds from these new issuances were used primarily to pay short-term borrowings and repay long-term debt at maturity. In 2017, Eversource, NSTAR Electric, CL&P, PSNH and NSTAR Gas repaid, at maturity, $745 million, $400 million, $250 million, $70 million and $25 million, respectively, of previously issued long-term debt.

- In 2017, we paid cash dividends on common shares of $602.1 million, compared with $564.5 million in 2016. On February 7, 2018, our Board of Trustees approved a common share dividend of $0.505 per share, payable on March 30, 2018 to shareholders of



record as of March 6, 2018. The 2018 dividend represents an increase of 6.3 percent over the dividend paid in December 2017, and is the equivalent to dividends on common shares of approximately $640 million on an annual basis.

- We project to make capital expenditures of $10.8 billion from 2018 through 2021, of which we expect $5.7 billion to be in our electric and natural gas distribution segments, $4.1 billion to be in our electric transmission segment and $0.4 billion to be in our water utility business. We also project to invest $0.5 billion in information technology and facilities upgrades and enhancements. These projections do not include any expected investments related to Bay State Wind.

## Strategic Items:

- On January 25, 2018, Northern Pass was selected from the 46 proposals submitted as the winning bidder in the Massachusetts clean energy request for proposal ("RFP"), which successfully positioned Northern Pass to provide a firm delivery of hydropower to Massachusetts. Northern Pass is Eversource's planned 1,090 MW HVDC transmission line from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. On February 1, 2018, the New Hampshire Site Evaluation Committee ("NHSEC") voted to deny Northern Pass' siting application. We intend to seek reconsideration of the NHSEC's decision and to review all options for moving this critical clean energy project forward. As of December 31, 2017, we have approximately $277 million in capitalized costs associated with Northern Pass.

- On December 20, 2017, Bay State Wind submitted two proposals, one for 400 MW and the other for 800 MW, in response to the Massachusetts clean energy RFP.

- On December 4, 2017, Eversource completed the acquisition of Aquarion (formerly Macquarie Utilities Inc.) from Macquarie Infrastructure Partners for $1.675 billion, consisting of approximately $880 million in cash and $795 million of assumed debt. As a result, Aquarion became a wholly-owned subsidiary of Eversource.

## Legislative, Regulatory, Policy and Other Items:

- On November 30, 2017, the DPU issued its decision in the NSTAR Electric distribution rate case, which approved an annual distribution rate increase of $37 million, with rates effective February 1, 2018. As a result of this decision, we recognized an aggregate $44.1 million pre-tax benefit to earnings in 2017. On January 3, 2018, NSTAR Electric filed a motion to reflect a revenue requirement reduction of $56 million due to the decrease in the federal corporate income tax rate, as part of the "Tax Cuts and Jobs Act", resulting in an annual net decrease in rates of $19 million.

- On January 11, 2018, CL&P filed a distribution rate case settlement agreement for approval with PURA, which included, among other things, rate increases of $97.1 million, $32.7 million and $24.7 million, effective May 1, 2018, 2019, and 2020, respectively, an authorized regulatory ROE of 9.25 percent, and 53 percent common equity in CL&P's capital structure. The rate increases associated with the settlement agreement will be reduced by the impact of the decrease in the federal corporate income tax rate, as part of the "Tax Cuts and Jobs Act", which we currently estimate to average approximately $45 million to $50 million per year.

- On December 22, 2017, the "Tax Cuts and Jobs Act" (the "Act") became law, which amended existing federal tax rules and included numerous provisions that impacted corporations. In particular, the Act reduced the federal corporate income tax rate from 35 percent to 21 percent effective January 1, 2018. As of December 31, 2017, we estimated approximately $2.9 billion of provisional regulated excess ADIT liabilities that we expect to benefit our customers in future periods. The ultimate amount and timing of when certain income tax benefits resulting from the Act benefit our customers will vary by jurisdiction.

- On January 10, 2018, PSNH completed the sale of its thermal generation facilities. In accordance with the Purchase and Sale 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, resulting in net proceeds of $134.1 million. We are targeting for PSNH to complete the sale of its hydroelectric generation facilities by the end of the first quarter of 2018.

## Overview

Consolidated: Below is a summary of our earnings by business, which also reconciles the non-GAAP financial measure of EPS by business to the most directly comparable GAAP measure of diluted EPS, for the years ended December 31, 2017, 2016 and 2015. Also included in the summary for the year ended December 31, 2015, is a reconciliation of the non-GAAP financial measure of consolidated non-GAAP earnings to the most directly comparable GAAP measure of consolidated Net Income Attributable to Common Shareholders.

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars, Except Per Share Amounts)</td><td colspan="3">2017</td><td colspan="3">2016</td><td colspan="3">2015</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>$</td><td>988.0</td><td>$</td><td>3.11</td><td>$</td><td>942.3</td><td>$</td><td>2.96</td><td>$</td></tr><tr><td>Electric and Natural Gas Companies</td><td>$</td><td>963.9</td><td>$</td><td>3.03</td><td>$</td><td>911.3</td><td>$</td><td>2.86</td><td>$</td></tr><tr><td>Eversource Parent and Other Companies</td><td></td><td>24.1</td><td></td><td>0.08</td><td></td><td>31.0</td><td></td><td>0.10</td><td></td></tr><tr><td>Non-GAAP Earnings</td><td></td><td>N/A</td><td></td><td>N/A</td><td></td><td>N/A</td><td></td><td>N/A</td><td></td></tr><tr><td>Integration Costs (after-tax) (1)</td><td></td><td>—</td><td></td><td>—</td><td></td><td>—</td><td></td><td>—</td><td>(15.8)</td></tr><tr><td>Net Income Attributable to Common Shareholders (GAAP)</td><td>$</td><td>988.0</td><td>$</td><td>3.11</td><td>$</td><td>942.3</td><td>$</td><td>2.96</td><td>$</td></tr></table>



(1) The 2015 integration costs were associated with our branding efforts and severance costs.

Electric and Natural Gas Companies: Our electric and natural gas companies consist of the electric distribution (including PSNH's generation facilities and NSTAR Electric's solar power facilities), electric transmission and natural gas distribution segments. A summary of our segment earnings and EPS is as follows:

<table><tr><td rowspan="2">(Millions of Dollars, Except Per Share Amounts)</td><td colspan="7">For the Years Ended December 31,</td></tr><tr><td colspan="2">2017</td><td colspan="2">2016</td><td colspan="2">2015</td><td></td></tr><tr><td>Electric Distribution</td><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>Electric Transmission</td><td>$ 497.4</td><td>$ 1.57</td><td>$ 462.8</td><td>$ 1.46</td><td>$ 507.9</td><td>$ 1.59</td><td></td></tr><tr><td>Natural Gas Distribution</td><td>391.9</td><td>1.23</td><td>370.8</td><td>1.16</td><td>304.5</td><td>0.96</td><td></td></tr><tr><td>Non-GAAP Earnings</td><td>74.6</td><td>0.23</td><td>77.7</td><td>0.24</td><td>72.4</td><td>0.23</td><td></td></tr><tr><td>Integration Costs (after-tax) (1)</td><td>N/A</td><td>N/A</td><td>N/A</td><td>N/A</td><td>884.8</td><td>2.78</td><td></td></tr><tr><td>Net Income - Electric and Natural Gas Companies</td><td>$ 963.9</td><td>$ 3.03</td><td>$ 911.3</td><td>$ 2.86</td><td>$ 884.0</td><td>$ 2.78</td><td></td></tr></table>

(1) The 2015 Electric and Natural Gas Companies' integration costs include severance in connection with cost saving initiatives.

Our electric distribution segment earnings increased $34.6 million in 2017, as compared to 2016, due primarily to a lower effective tax rate, lower non-tracked operations and maintenance expense, higher lost base revenues at NSTAR Electric and higher distribution revenues at CL&P due in part to a higher rate base for the system resiliency program, partially offset by higher depreciation expense, lower sales volumes primarily driven by the mild summer weather in 2017, as compared to 2016 (primarily at NSTAR Electric), and higher property tax expense.

Our electric transmission segment earnings increased $21.1 million in 2017, as compared to 2016, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure, partially offset by the absence in 2017 of the FERC-allowed recovery of certain previously expensed merger-related costs in 2016, and a lower benefit in the second quarter of 2017 related to the annual billing and cost reconciliation filing with the FERC.

Our natural gas distribution segment earnings decreased $3.1 million in 2017, as compared to 2016, due primarily to higher depreciation expense, lower demand revenues in Connecticut driven by lower peak usage in 2017, as compared to 2016, higher non-tracked operations and maintenance expense, and higher property tax expense, partially offset by higher sales volumes driven by colder winter weather in the fourth quarter of 2017, as compared to 2016.

Eversource Parent and Other Companies: Eversource parent and other companies earned $24.1 million in 2017, compared with $31.0 million in 2016. The decrease in earnings was due primarily to a higher effective tax rate, higher interest expense and the absence in 2017 of the earnings and gain on the sale of an unregulated business in 2016. These decreases were partially offset by the 2017 DPU-allowed recovery of certain previously expensed merger-related costs in NSTAR Electric's distribution rates, and increased gains on investments recorded in 2017.

Electric and Natural Gas Sales Volumes: Weather, fluctuations in energy supply costs, conservation measures (including utility-sponsored energy efficiency programs), and economic conditions affect customer energy usage. Industrial sales volumes are less sensitive to temperature variations than residential and commercial sales volumes. In our service territories, weather impacts electric 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 are 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 certain of our electric utilities impact earnings ("Traditional" in the table below). For others, fluctuations in retail electric sales volumes do not impact earnings due to their regulatory commission approved distribution revenue decoupling mechanisms ("Decoupled" in the table below). These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized.

In 2017 and 2016, NSTAR Electric operated under two different rate structures based on its service territory geography. For customers that were served in eastern Massachusetts, including metropolitan Boston, Cape Cod and Martha's Vineyard, NSTAR Electric operated using Traditional rates. For customers that were served in western Massachusetts, including the metropolitan Springfield region, NSTAR Electric operated using Decoupled rates. Effective February 1, 2018, all of NSTAR Electric's distribution revenues were decoupled as a result of the DPU-approved rate decision. See "Regulatory Developments and Rate Matters - Massachusetts - NSTAR Electric Distribution Rate Case Decision" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

CL&P and NSTAR Electric (for its western Massachusetts customer rates) reconciled their annual base distribution rate recovery amounts to their pre-established levels of baseline distribution delivery service revenues of $1.059 billion and $132.4 million, respectively, through December 31, 2017. Effective February 1, 2018, NSTAR Electric, operating entirely under decoupled rates, will reconcile its annual base distribution rate recovery to its new baseline of $974.8 million. 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.

Fluctuations in natural gas sales volumes in Connecticut impact earnings ("Traditional" in the table below). In Massachusetts, fluctuations in natural gas sales volumes do not impact earnings due to the DPU-approved natural gas distribution revenue decoupling mechanism approved in



the last rate case decision ("Decoupled" in the table below). These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized.

A summary of our retail electric GWh sales volumes and our firm natural gas sales volumes in MMcf and percentage changes is as follows:

<table><tr><td rowspan="4"></td><td colspan="3">Electric</td><td colspan="3">Firm Natural Gas</td></tr><tr><td colspan="3">For the Year Ended December 31, 2017 Compared to 2016</td><td colspan="3">For the Year Ended December 31, 2017 Compared to 2</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/(Decrease)</td></tr><tr><td>2017</td><td>2016</td><td>2017</td><td>2016</td></tr><tr><td>Traditional:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>9,453</td><td>9,654</td><td>(2.1)%</td><td>15,502</td><td>15,118</td><td>2.5%</td></tr><tr><td>Commercial</td><td>15,958</td><td>16,267</td><td>(1.9)%</td><td>20,649</td><td>19,846</td><td>4.0%</td></tr><tr><td>Industrial</td><td>2,444</td><td>2,558</td><td>(4.5)%</td><td>10,806</td><td>10,350</td><td>4.4%</td></tr><tr><td>Total - Traditional</td><td>27,855</td><td>28,479</td><td>(2.2)%</td><td>46,957</td><td>45,314</td><td>3.6%</td></tr><tr><td>Decoupled:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>11,043</td><td>11,347</td><td>(2.7)%</td><td>21,919</td><td>20,616</td><td>6.3%</td></tr><tr><td>Commercial</td><td>10,612</td><td>10,940</td><td>(3.0)%</td><td>21,859</td><td>21,583</td><td>1.3%</td></tr><tr><td>Industrial</td><td>2,736</td><td>2,876</td><td>(4.9)%</td><td>5,882</td><td>5,833</td><td>0.8%</td></tr><tr><td>Total - Decoupled</td><td>24,391</td><td>25,163</td><td>(3.1)%</td><td>49,660</td><td>48,032</td><td>3.4%</td></tr><tr><td>Special Contracts \( ^{(1)} \)</td><td>N/A</td><td>N/A</td><td>N/A</td><td>4,409</td><td>4,696</td><td>(6.1)%</td></tr><tr><td>Total - Decoupled and Special Contracts</td><td>24,391</td><td>25,163</td><td>(3.1)%</td><td>54,069</td><td>52,728</td><td>2.5%</td></tr><tr><td>Total Sales Volumes</td><td>52,246</td><td>53,642</td><td>(2.6)%</td><td>101,026</td><td>98,042</td><td>3.0%</td></tr></table>

(1) Special contracts are unique to the 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.

Retail electric sales volumes at our electric utilities with a traditional rate structure (the eastern region of NSTAR Electric and PSNH) were lower in 2017, as compared to 2016, due primarily to the mild summer weather in 2017, as compared to 2016. Cooling degree days in 2017 were 14.7 percent lower in the Boston metropolitan area and 22.7 percent lower in New Hampshire, as compared to 2016. Sales volumes were positively impacted by improved economic conditions across our service territories, but this trend was offset by lower customer usage driven by the impact of increased customer energy conservation efforts.

On January 28, 2016, Eversource received approval of a three-year energy efficiency plan in Massachusetts, which included recovery of LBR in the NSTAR Electric eastern Massachusetts service territory until it was covered under a decoupled rate structure, which occurred on February 1, 2018. NSTAR Electric recorded LBR related to reductions in sales volume as a result of successful energy efficiency programs. LBR was recovered from retail customers through rates. NSTAR Electric recognized LBR of $73.7 million and $60.7 million in 2017 and 2016, respectively.

Our firm natural gas sales volumes are subject to many of the same influences as our retail electric sales volumes. In addition, they have benefited from customer growth in both of our natural gas distribution companies. Consolidated firm natural gas sales volumes were higher in 2017, as compared to 2016, due primarily to colder winter weather in the fourth quarter of 2017, as compared to 2016. Heating degree days in 2017 were 2.5 percent higher in Connecticut, as compared to 2016. Sales volumes were also positively impacted by improved economic conditions across our natural gas service territories.

## Liquidity

Consolidated: Cash and cash equivalents totaled $38.2 million as of December 31, 2017, compared with $30.3 million as of December 31, 2016.



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

<table><tr><td rowspan="2">(Millions of Dollars)</td><td rowspan="2">Issue Date</td><td rowspan="2">Issuances/(Repayments)</td><td rowspan="2">Maturity Date</td><td rowspan="2">Use of Proceeds</td></tr><tr></tr><tr><td>CL&amp;P:</td><td></td><td></td><td></td><td></td></tr><tr><td>3.20% 2017 Series A First Mortgage Bonds</td><td>March 2017</td><td>$ 300.0</td><td>2027</td><td>Repay short-term debt borrowings</td></tr><tr><td>4.30% 2014 Series A First Mortgage Bonds (1)</td><td>August 2017</td><td>225.0</td><td>2044</td><td>Refinance short-term debt and fund working capital and capital expenditures</td></tr><tr><td>5.375% 2007 Series A First Mortgage Bonds</td><td>March 2007</td><td>(150.0)</td><td>2017</td><td>N/A</td></tr><tr><td>5.75% 2007 Series C First Mortgage Bonds</td><td>September 2007</td><td>(100.0)</td><td>2017</td><td>N/A</td></tr><tr><td>NSTAR Electric:</td><td></td><td></td><td></td><td></td></tr><tr><td>3.20% Debentures</td><td>May 2017</td><td>350.0</td><td>2027</td><td>Repay short-term borrowings and fund capital expenditures and working capital</td></tr><tr><td>3.20% Debentures (2)</td><td>October 2017</td><td>350.0</td><td>2027</td><td>Redeem long-term debt that matured in 2017</td></tr><tr><td>5.625% Debentures</td><td>November 2007</td><td>(400.0)</td><td>2017</td><td>N/A</td></tr><tr><td>PSNH:</td><td></td><td></td><td></td><td></td></tr><tr><td>6.15% Series N First Mortgage Bonds</td><td>September 2007</td><td>(70.0)</td><td>2017</td><td>N/A</td></tr><tr><td>Other:</td><td></td><td></td><td></td><td></td></tr><tr><td>Yankee Gas 3.02% Series N First Mortgage Bonds</td><td>September 2017</td><td>75.0</td><td>2027</td><td>Repay short-term borrowings</td></tr><tr><td>NSTAR Gas 7.04% Series M First Mortgage Bonds</td><td>September 1997</td><td>(25.0)</td><td>2017</td><td>N/A</td></tr><tr><td>Eversource Parent 2.75% Series K Senior Notes</td><td>March 2017</td><td>300.0</td><td>2022</td><td>Repay short-term borrowings</td></tr><tr><td>Eversource Parent 2.75% Series K Senior Notes (3)</td><td>October 2017</td><td>450.0</td><td>2022</td><td>Repay short-term borrowings</td></tr><tr><td>Eversource Parent 2.90% Series L Senior Notes</td><td>October 2017</td><td>450.0</td><td>2024</td><td>Repay short-term borrowings</td></tr><tr><td>Eversource Parent 2.50% Series I Senior Notes (4)</td><td>January 2018</td><td>200.0</td><td>2021</td><td>Repay long-term debt due to mature in 2018 and repay short-term borrowings</td></tr><tr><td>Eversource Parent 3.30% Series M Senior Notes</td><td>January 2018</td><td>450.0</td><td>2028</td><td>Repay long-term debt due to mature in 2018</td></tr><tr><td>Eversource Parent 1.60% Series G Senior Notes (5)</td><td>January 2015</td><td>(150.0)</td><td>2018</td><td>N/A</td></tr></table>

(1) These bonds are part of the existing series initially issued by CL&P in 2014. The aggregate outstanding principal amount for these bonds is now $475 million.
(2) These debentures are part of the same series initially issued by NSTAR Electric in May 2017. The aggregate outstanding principal amount for these debentures is now $700 million.

(3) These notes are part of the same series issued by Eversource parent in March 2017. The aggregate outstanding principal amount for these notes is now $750 million.

(4) These notes are part of the same series issued by Eversource parent in March 2016. The aggregate outstanding principal amount for these notes is now $450 million.

(5) Represents a repayment at maturity on January 15, 2018.

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 and Yankee Gas are also parties to a five-year $1.45 billion revolving credit facility. On December 8, 2017, Eversource parent amended and restated the revolving credit facility. The amended and restated revolving credit facility terminates on December 8, 2022 and serves to backstop Eversource parent's $1.45 billion commercial paper program. There were no borrowings outstanding on the revolving credit facility as of December 31, 2017 or 2016.

NSTAR Electric has a $650 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. On December 8, 2017, NSTAR Electric increased its commercial paper program from $450 million to $650 million. NSTAR Electric is also a party to a five-year $650 million revolving credit facility. On December 8, 2017, NSTAR Electric amended and restated the revolving credit facility, increasing it from $450 million to $650 million. The amended and restated revolving credit facility terminates on December 8, 2022 and serves to backstop NSTAR Electric's $650 million commercial paper program. There were no borrowings outstanding on the revolving credit facility as of December 31, 2017 or 2016.

The amount of borrowings outstanding and available under the commercial paper programs and revolving credit facility was 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>2017</td><td>2016</td><td>2017</td><td>2016</td><td>2017</td><td>2016</td><td>2017</td><td></td></tr><tr><td>Eversource Parent Commercial Paper Program</td><td>$ 979.3</td><td>$ 1,022.0</td><td>$ 470.7</td><td>$ 428.0</td><td>1.86%</td><td>0.88%</td><td></td><td></td></tr><tr><td>NSTAR Electric Commercial Paper Program</td><td>234.0</td><td>126.5</td><td>416.0</td><td>323.5</td><td>1.55%</td><td>0.71%</td><td></td><td></td></tr><tr><td>Revolving Credit Facility (1)</td><td>76.0</td><td>N/A</td><td>24.0</td><td>N/A</td><td>2.66%</td><td>N/A</td><td></td><td></td></tr></table>

(1) Aquarion has a $100.0 million revolving credit facility, which expires on August 19, 2019.

Amounts outstanding under the commercial paper programs and revolving credit facility are included in Notes Payable for Eversource and NSTAR Electric and are classified in current liabilities on the 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 issuances on January 8, 2018, the net proceeds of which were used to repay short-term borrowings



outstanding under its commercial paper program, $201.2 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt as of December 31, 2017.

As of December 31, 2017, there were intercompany loans from Eversource parent of $69.5 million to CL&P and $262.9 million to PSNH. As of December 31, 2016, there were intercompany loans from Eversource parent of $80.1 million to CL&P, $160.9 million to PSNH and $51.0 million to NSTAR Electric. These intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and are classified in current liabilities on the respective subsidiary's balance sheets. Intercompany loans from Eversource parent are eliminated in consolidation on Eversource's balance sheets.

Cash Flows: Cash flows provided by operating activities totaled $2.0 billion in 2017, compared with $2.2 billion in 2016. The decrease in operating cash flows was due primarily to the $166.3 million net unfavorable impact as a result of the change in income tax payments made, or refunds received, in 2017 when compared to 2016. This unfavorable impact was primarily the result of the December 2015 legislation, which extended the accelerated deduction of depreciation from 2015 to 2019. The legislation resulted in a significant refund of approximately $275 million, which we received in the first quarter of 2016. Additionally, there was an increase of $84.1 million in Pension and PBOP Plan cash contributions made in 2017, as compared to 2016, a decrease of $59.8 million related to the absence in 2017 of the Yankee Companies' DOE Damages received in 2016, and the unfavorable impact related to the timing of regulatory recoveries, which were significantly impacted by NSTAR Electric's timing of collections of purchased power and transmission costs. Partially offsetting these unfavorable impacts was the benefit related to the timing of collections and payments of our working capital items, including accounts payable.

In 2017, we paid cash dividends of $602.1 million, or $1.90 per common share, compared with $564.5 million, or $1.78 per common share in 2016. Our quarterly common share dividend payment was $0.475 per share, in 2017, as compared to $0.445 per common share in 2016. On February 7, 2018, our Board of Trustees approved a common share dividend of $0.505 per share, payable on March 30, 2018 to shareholders of record as of March 6, 2018. The 2018 dividend represents an increase of 6.3 percent over the dividend paid in December 2017, and is the equivalent to dividends on common shares of approximately $640 million on an annual basis.

In 2017, CL&P, NSTAR Electric and PSNH paid $254.8 million, $272.0 million and $23.9 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 portions of pension expense. In 2017, investments for Eversource, CL&P, NSTAR Electric and PSNH were $2.3 billion, $824.4 million, $719.6 million and $312.7 million, respectively.

Eversource completed the acquisition of Aquarion from Macquarie Infrastructure Partners on December 4, 2017 for $1.675 billion, consisting of approximately $880 million in cash and $795 million of assumed debt.

Eversource, CL&P, NSTAR Electric and PSNH each use 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 and natural gas 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 $2.3 billion in cash capital spend in 2017. In addition, growth in Eversource's key business initiatives in 2017 required cash contributions of $32.6 million, which are recognized as long-term assets. These factors have resulted in current liabilities exceeding current assets by $1.1 billion, $338.1 million, $137.5 million, and $183.1 million at Eversource, CL&P, NSTAR Electric and PSNH, respectively, as of December 31, 2017.

As of December 31, 2017, $961.0 million of Eversource's long-term debt, including $450.0 million, $300.0 million, $110.0 million, $100.0 million and $1 million for Eversource parent, CL&P, PSNH, Yankee Gas and Aquarion, respectively, will be paid within the next 12 months. Included in the current portion of long-term debt is $35.4 million related to fair value adjustments from our 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 the access to financial markets, will be sufficient to meet any future operating requirements and capital investment forecasted opportunities.

Credit Ratings: On December 5, 2017, S&P upgraded Eversource and its subsidiaries' corporate credit rating to A+ and changed the outlook to stable.

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>Positive</td></tr><tr><td>CL&amp;P</td><td>Baa1</td><td>Stable</td><td>A+</td><td>Stable</td><td>A-</td><td>Stable</td></tr><tr><td>NSTAR Electric</td><td>A2</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>A</td><td>Stable</td><td>BBB+</td><td>Positive</td></tr><tr><td>CL&amp;P</td><td>A2</td><td>Stable</td><td>AA-</td><td>Stable</td><td>A+</td><td>Stable</td></tr><tr><td>NSTAR Electric</td><td>A2</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>AA-</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 portions of pension expense (all of which are non-cash factors), totaled $2.5 billion in 2017, $2.2 billion in 2016, and $1.9 billion in 2015. These amounts included $165.9 million in 2017, $137.7 million in 2016, and $102.0 million in 2015 related to information technology and facilities upgrades and enhancements, primarily at Eversource Service and The Rocky River Realty Company.

Aquarion: On December 4, 2017, Eversource acquired Aquarion (formerly Macquarie Utilities Inc.) from Macquarie Infrastructure Partners for $1.675 billion, consisting of approximately $880 million in cash and $795 million of assumed Aquarion debt. As a result, Aquarion became a wholly-owned subsidiary of Eversource. Aquarion is a regulated water utility holding company that operates three separate regulated water utilities in Connecticut, Massachusetts and New Hampshire. Aquarion collects, treats and distributes water to residential, commercial and industrial customers, to other utilities for resale, and for private and municipal fire protection.

Bay State Wind: Bay State Wind is a proposed offshore wind project being jointly developed by Eversource and Denmark-based Ørsted. Bay State Wind will be located in a 300-square-mile area approximately 25 miles off the coast of Massachusetts that has the ultimate potential to generate more than 2,000 MW of clean, renewable energy. Eversource and Ørsted each hold a 50 percent ownership interest in Bay State Wind.

On June 29, 2017, the Bureau of Ocean Energy Management ("BOEM") approved the project’s Site Assessment Plan ("SAP"), the first BOEM approval of an offshore wind SAP in the U.S.

In August 2016, Massachusetts passed clean energy legislation that requires EDCs to jointly solicit RFPs and enter into long-term contracts for offshore wind, creating RFP opportunities for projects like Bay State Wind. On June 29, 2017, the Massachusetts RFP was issued, seeking bids for a minimum of 400 MW of offshore wind capacity. The RFP stated that bids of up to 800 MW would be considered, provided they demonstrated significant net economic benefits to customers. On December 20, 2017, Bay State Wind submitted two proposals, one for 400 MW and the other for 800 MW, in response to the Massachusetts clean energy RFP.

For more information regarding the clean energy legislation, see "Regulatory Developments and Rate Matters – Massachusetts – Massachusetts RFPs" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

## Electric Transmission Business:

Our consolidated electric transmission business capital expenditures increased by $35.4 million in 2017, as compared to 2016. 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>2017</td><td>2016</td><td>2015</td></tr><tr><td>CL&amp;P</td><td>$ 431.5</td><td>$ 338.3</td><td>$ 252.9</td></tr><tr><td>NSTAR Electric</td><td>301.9</td><td>398.7</td><td>354.2</td></tr><tr><td>PSNH</td><td>155.6</td><td>119.0</td><td>161.2</td></tr><tr><td>NPT</td><td>43.3</td><td>40.9</td><td>38.3</td></tr><tr><td>Total Electric Transmission Segment</td><td>$ 932.3</td><td>$ 896.9</td><td>$ 806.6</td></tr></table>

Northern Pass: Northern Pass is Eversource's planned 1,090 MW HVDC transmission line that will interconnect from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire.

Northern Pass has achieved several key milestones, including the following:

• Receiving NHPUC approval on February 12, 2018 for the proposed lease of certain land and easement rights from PSNH to NPT, concluding that the lease is in the public interest;

• Receiving the U.S. Forest Service Record of Decision on January 5, 2018, which allows NPT to install approximately 11 miles of underground transmission lines in areas along existing roads through the White Mountain National Forest;

• Receiving the Province of Québec permit granted to HQ on December 21, 2017 to construct the hydroelectric transmission line that will connect at the border of New Hampshire;

• Receiving the DOE Record of Decision and Presidential Permit on November 16, 2017, which will allow construction of transmission facilities at the Québec-New Hampshire border; and

• Receiving the DOE final Environmental Impact Statement issued on August 10, 2017, which concluded that the proposed Northern Pass route is the preferred alternative, providing substantial benefits with only minimal impacts.



On January 25, 2018, Northern Pass was selected from the 46 proposals submitted as the winning bidder in the Massachusetts clean energy request for proposal ("RFP"), which successfully positioned Northern Pass to provide a firm delivery of hydropower to Massachusetts. On February 1, 2018, the NHSEC voted to deny Northern Pass' siting application. On February 14, 2018, pursuant to the NHSEC's decision, the Massachusetts EDCs, in coordination with the DOER and an independent evaluator, notified NPT that the EDCs will continue contract negotiations, with the option of discontinuing discussions and terminating its conditional selection by March 27, 2018.

Consistent with Eversource’s and HQ’s long-term relationship to bring clean energy into New England, Eversource and HQ continue to support Northern Pass and the many benefits this project will bring to our customers and region. We intend to seek reconsideration of the NHSEC’s decision and to review all options for moving this critical clean energy project forward.

As of December 31, 2017, we have approximately $277 million in capitalized costs associated with Northern Pass. We continue to believe that the Northern Pass project is probable of being placed in service. If in the future, events and changes in circumstances indicate that the Northern Pass project's capitalized costs may not be fully recoverable, we will then evaluate those costs for impairment. Should we conclude that these capitalized costs are impaired, this would have a significant negative impact on our financial position, results of operations, and cash flows. For more information regarding the Massachusetts clean energy RFP, see "Regulatory Developments and Rate Matters – Massachusetts – Massachusetts RFPs" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

Greater Boston Reliability Solution: In February 2015, ISO-NE selected the Greater Boston and New Hampshire Solution (the "Solution"), proposed by Eversource and National Grid, to satisfy the requirements identified in the Greater Boston study. The Solution consists of a portfolio of electric transmission upgrades covering southern New Hampshire and northern Massachusetts and continuing into the greater Boston metropolitan area, of which 28 upgrades are in Eversource's service territory. The NHSEC issued its written order approving the New Hampshire upgrades on October 4, 2016. We are currently pursuing the necessary regulatory and siting application approvals in Massachusetts. To date, we have received approval for three of these projects from the Massachusetts Energy Facilities Siting Board. Construction has also begun on multiple smaller projects, several of which have been placed in service. All upgrades are expected to be completed by the end of 2019. We estimate our portion of the investment in the Solution will be approximately $560 million, of which $235.8 million has been capitalized through December 31, 2017.

GHCC: The Greater Hartford Central Connecticut ("GHCC") projects, which have been approved by ISO-NE, consist of 27 projects with an expected investment of approximately $350 million that are expected to be placed in service through 2019. As of December 31, 2017, 18 projects have been placed in service, and six projects are in active construction. As of December 31, 2017, CL&P had capitalized $210.0 million in costs associated with GHCC.

Seacoast Reliability Project: On April 12, 2016, PSNH filed a siting application with the NHSEC for the Seacoast Reliability Project, a 13-mile, 115kV transmission line within several New Hampshire communities, which proposes to use a combination of overhead, underground and underwater line design to help meet the growing demand for electricity in the Seacoast region. In June 2016, the NHSEC accepted our application as complete. The New Hampshire Department of Environmental Services has experienced delays with the issuance of permit conditions and now expects to complete its review in February 2018. As a result, siting hearings have yet to be rescheduled and we now expect the NHSEC decision in late-2018. This project is expected to be completed by the end of 2019. We estimate our investment in this project to be approximately $84 million, of which, PSNH had capitalized $24.5 million in costs, through December 31, 2017.



A summary of distribution capital expenditures by company is as follows:

<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>Total Electric and Natural Gas Distribution Segments</td><td></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>$ 515.0</td><td></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>583.8</td><td></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>209.8</td><td></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>1,308.6</td><td></td><td></td><td></td></tr><tr><td>Solar Power and Generation</td><td>—</td><td>100.1</td><td>8.5</td><td>108.6</td><td>—</td><td>108.6</td><td></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>$ 1,417.2</td><td></td><td></td><td></td></tr><tr><td>2016</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>$ 179.8</td><td>$ 146.0</td><td>$ 70.0</td><td>$ 395.8</td><td>$ 70.7</td><td>$ 466.5</td><td></td><td></td><td></td></tr><tr><td>Aging Infrastructure</td><td>144.7</td><td>105.7</td><td>84.7</td><td>335.1</td><td>155.9</td><td>491.0</td><td></td><td></td><td></td></tr><tr><td>Load Growth and Other</td><td>48.6</td><td>89.2</td><td>17.3</td><td>155.1</td><td>44.2</td><td>199.3</td><td></td><td></td><td></td></tr><tr><td>Total Distribution</td><td>373.1</td><td>340.9</td><td>172.0</td><td>886.0</td><td>270.8</td><td>1,156.8</td><td></td><td></td><td></td></tr><tr><td>Generation</td><td>—</td><td>—</td><td>17.5</td><td>17.5</td><td>—</td><td>17.5</td><td></td><td></td><td></td></tr><tr><td>Total</td><td>$ 373.1</td><td>$ 340.9</td><td>$ 189.5</td><td>$ 903.5</td><td>$ 270.8</td><td>$ 1,174.3</td><td></td><td></td><td></td></tr><tr><td>2015</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>$ 141.1</td><td>$ 126.9</td><td>$ 59.2</td><td>$ 327.2</td><td>$ 46.8</td><td>$ 374.0</td><td></td><td></td><td></td></tr><tr><td>Aging Infrastructure</td><td>151.0</td><td>121.6</td><td>57.3</td><td>329.9</td><td>122.3</td><td>452.2</td><td></td><td></td><td></td></tr><tr><td>Load Growth and Other</td><td>42.2</td><td>58.5</td><td>25.5</td><td>126.2</td><td>43.5</td><td>169.7</td><td></td><td></td><td></td></tr><tr><td>Total Distribution</td><td>334.3</td><td>307.0</td><td>142.0</td><td>783.3</td><td>212.6</td><td>995.9</td><td></td><td></td><td></td></tr><tr><td>Generation</td><td>—</td><td>—</td><td>33.3</td><td>33.3</td><td>—</td><td>33.3</td><td></td><td></td><td></td></tr><tr><td>Total</td><td>$ 334.3</td><td>$ 307.0</td><td>$ 175.3</td><td>$ 816.6</td><td>$ 212.6</td><td>$ 1,029.2</td><td></td><td></td><td></td></tr></table>

For the electric distribution business, basic business includes the purchase of meters, tools, vehicles, information technology, transformer replacements, equipment facilities, and the relocation of plant. Aging infrastructure relates to reliability and the replacement of overhead lines, plant substations, underground cable replacement, and equipment failures. Load growth and other includes requests for new business and capacity additions on distribution lines and substation additions and expansions. For the natural gas distribution business, basic business addresses daily operational needs including meters, pipe relocations due to public works projects, vehicles, and tools. Aging infrastructure projects seek to improve the reliability of the system through enhancements related to cast iron and bare steel replacement of main and services, corrosion mediation, and station upgrades. Load growth and other reflects growth in existing service territories including new developments, installation of services, and expansion.

The natural gas distribution segment’s capital spending program increased by $64.5 million in 2017, as compared to 2016, primarily due to an increased investment in system replacement and reliability, as well as upgrades to our LNG facilities. We expect the LNG facility upgrades to cost approximately $200 million and to be placed in service in late 2019.

Projected Capital Expenditures: A summary of the projected capital expenditures for the regulated companies' electric transmission and for the total electric distribution, solar development and natural gas distribution businesses for 2018 through 2021, 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="7">Years</td></tr><tr><td>2018</td><td>2019</td><td>2020</td><td>2021</td><td>2018-2021 Total</td><td></td><td></td></tr><tr><td>CL&amp;P Transmission</td><td>$ 390</td><td>$ 228</td><td>$ 155</td><td>$ 128</td><td>$ 901</td><td></td><td></td></tr><tr><td>NSTAR Electric Transmission</td><td>333</td><td>293</td><td>267</td><td>248</td><td>1,141</td><td></td><td></td></tr><tr><td>PSNH Transmission</td><td>149</td><td>144</td><td>138</td><td>147</td><td>578</td><td></td><td></td></tr><tr><td>NPT</td><td>300</td><td>718</td><td>436</td><td>70</td><td>1,524</td><td></td><td></td></tr><tr><td>Total Electric Transmission</td><td>$ 1,172</td><td>$ 1,383</td><td>$ 996</td><td>$ 593</td><td>$ 4,144</td><td></td><td></td></tr><tr><td>Electric Distribution</td><td>$ 1,094</td><td>$ 963</td><td>$ 984</td><td>$ 940</td><td>$ 3,981</td><td></td><td></td></tr><tr><td>Solar Development</td><td>76</td><td>—</td><td>—</td><td>—</td><td>76</td><td></td><td></td></tr><tr><td>Natural Gas Distribution</td><td>422</td><td>425</td><td>380</td><td>389</td><td>1,616</td><td></td><td></td></tr><tr><td>Total Distribution</td><td>$ 1,592</td><td>$ 1,388</td><td>$ 1,364</td><td>$ 1,329</td><td>$ 5,673</td><td></td><td></td></tr><tr><td>Water</td><td>$ 100</td><td>$ 102</td><td>$ 108</td><td>$ 125</td><td>$ 435</td><td></td><td></td></tr><tr><td>Information Technology and All Other</td><td>$ 178</td><td>$ 124</td><td>$ 111</td><td>$ 112</td><td>$ 525</td><td></td><td></td></tr><tr><td>Total</td><td>$ 3,042</td><td>$ 2,997</td><td>$ 2,579</td><td>$ 2,159</td><td>$ 10,777</td><td></td><td></td></tr></table>



The projections do not include investments related to Bay State Wind. Actual capital expenditures could vary from the projected amounts for the companies and years above.

## FERC Regulatory Issues

FERC ROE Complaints: Four separate complaints have been 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, 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 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. The Court found that the FERC failed to make an explicit finding that the 11.14 percent base ROE was unjust and unreasonable, as required under Section 206 of the Federal Power Act, before it set a new base ROE. The Court also found that the FERC did not provide a rational connection between the record evidence and its decision to select the midpoint of the upper half of the zone of reasonableness for the new base ROE.

Hearings on the fourth complaint were held in December 2017 before the Administrative Law Judge ("ALJ"), who is expected to issue an initial decision in March 2018.

A summary of the four separate complaints and the base ROEs pertinent to those complaints are as follows:

<table><tr><td>Complaint</td><td>15-Month Time Period of Complaint (Beginning as of Complaint Filing Date)</td><td>Original Base ROE Authorized by FERC at Time of Complaint Filing Date (1)</td><td>Base ROE Subsequently Authorized by FERC for First Complaint Period and also Effective from October 16, 2014 through April 14, 2017 (1)</td><td>Reserve (Pre-Tax and Excluding Interest) as of December 31, 2017 (in millions)</td><td>FERC ALJ Recommendation of Base ROE on Second and Third Complaints (Issued March 22, 2016)</td></tr><tr><td>First</td><td>10/1/2011 - 12/31/2012</td><td>11.14%</td><td>10.57%</td><td>$—</td><td>N/A</td></tr><tr><td>Second</td><td>12/27/2012 - 3/26/2014</td><td>11.14%</td><td>N/A</td><td>39.1</td><td>9.59%</td></tr><tr><td>Third</td><td>7/31/2014 - 10/30/2015</td><td>11.14%</td><td>10.57%</td><td>—</td><td>10.90%</td></tr><tr><td>Fourth</td><td>4/29/2016 - 7/28/2017</td><td>10.57%</td><td>10.57%</td><td>—</td><td>N/A</td></tr></table>

(1) The ROE billed during the period October 1, 2011 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 an incentive cap at 11.74 percent for the first complaint period and also effective from the date of the FERC order on October 16, 2014. This FERC order was vacated on April 14, 2017.

(2) CL&P, NSTAR Electric and PSNH have refunded all amounts associated with the first complaint period, totaling $38.9 million (pre-tax and excluding interest) at Eversource (consisting of $22.4 million at CL&P, $13.7 million at NSTAR Electric and $2.8 million at PSNH), reflecting both the base ROE and incentive cap prescribed by the FERC order.

(3) The 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, 2017.

On June 5, 2017, the NETOs, including Eversource, submitted a filing to the FERC to reinstate the base ROE of 11.14 percent with an associated ROE incentive cap of 13.5 percent effective June 8, 2017, as these were the last ROEs lawfully in effect for transmission billing purposes prior to the FERC order vacated by the Court on April 14, 2017. On October 6, 2017, the FERC did not accept the NETOs filing, temporarily leaving in place the ROEs (10.57 percent base ROE with an 11.74 percent incentive cap ROE) set in the first complaint proceeding until the FERC addresses the Court’s decision. On November 6, 2017, the NETOs submitted a request for rehearing of the FERC’s October 6, 2017 Order rejecting the compliance filing.

On October 5, 2017, the NETOs filed a series of motions, requesting that the FERC dismiss the four complaint proceedings. Alternatively, if the FERC does not dismiss the proceedings, the NETOs requested that the FERC consolidate all four complaint proceedings for expeditious resolution and/or stay the trial in the fourth complaint proceeding and resolve it based on the standards set in the April 14, 2017 Court decision.

At this time, the Company cannot reasonably estimate a range of gain or loss for the complaint proceedings. No events in 2017 provided a reasonable basis for a change to the reserve balance of $39.1 million (pre-tax, excluding interest) for the second complaint period, and the Company has not changed its reserve or recognized ROEs for any of the complaint periods.

Management cannot at this time predict the ultimate effect of the Court decision or future FERC action on any of the complaint periods or the estimated impacts on the financial position, results of operations or cash flows of Eversource, CL&P, NSTAR Electric or PSNH.

The average impact of a 10 basis point change to the base ROE for each of the 15-month complaint periods would affect Eversource's after-tax earnings by approximately $3 million.



## 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 distribution rates were established in a 2014 PURA-approved rate case. On January 11, 2018, CL&P filed a distribution rate case settlement agreement for approval with PURA. See "Regulatory Developments and Rate Matters - Connecticut - CL&P Rate Case Settlement" in this Management's Discussion and Analysis of Financial Condition and Results of Operations, for more information. Yankee Gas distribution rates were established in a 2011 PURA-approved rate case. The requirement for Yankee Gas to file a base distribution rate case in 2015 was eliminated due to a rate review conducted by PURA and a resulting settlement in 2015 between Yankee Gas and PURA.

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. On November 30, 2017, the DPU approved the NSTAR Electric rate case application. See "Regulatory Developments and Rate Matters - Massachusetts - NSTAR Electric Distribution Rate Case Decision" in this Management's Discussion and Analysis of Financial Condition and Results of Operations, for more information. NSTAR Gas distribution rates were established in a 2015 DPU-approved rate case.

In New Hampshire, PSNH distribution rates were established in a settlement approved by the NHPUC in 2010. Prior to the expiration of that settlement, the NHPUC approved the continuation of those rates, and increased funding via rates, of PSNH's reliability enhancement program.

## Electric and Natural Gas Retail Rates:

The Eversource EDCs 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 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, such costs have no impact on earnings. Costs recovered through cost tracking mechanisms include energy efficiency program costs, electric transmission charges, electric federally mandated congestion charges, system resiliency costs, certain uncollectible hardship bad debt expenses, and restructuring and stranded costs resulting from deregulation. 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.

U.S. Federal Corporate Income Taxes: On December 22, 2017, the "Tax Cuts and Jobs Act" (the "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 will be (1) the benefit of incurring a lower federal income tax expense, which we expect to be passed back to customers, and (2) the provisional regulated excess ADIT liabilities that we expect to benefit our customers in future periods, which were estimated to be approximately $2.9 billion and recognized as regulatory liabilities as of December 31, 2017. We are currently working with our state regulatory commissions, who have opened investigations to examine the impact of the Act on customer rates. FERC has yet to address how the Act would impact transmission rates.

We will continue to evaluate the impacts of the Act on our statement of financial position, results of operations, and cash flows. The impacts will vary depending on the ultimate amount and timing of when certain income tax benefits will benefit our customers, and will vary by jurisdiction.

## Connecticut:

CL&P Rate Case Settlement: On April 20, 2017, PURA approved the joint request of CL&P, the Connecticut Office of Consumer Counsel ("OCC") and the Connecticut Attorney General to amend the deadline to establish new electric distribution rates in the 2012 Connecticut merger settlement agreement from "no later than December 1, 2017" to "no later than July 1, 2018." On November 22, 2017, CL&P filed its application with PURA, which sought a rate increase of $255.8 million, $45.0 million and $36.0 million effective in May 2018, 2019, and 2020, respectively. On December, 15, 2017, CL&P, the Prosecutorial Unit of PURA, and the OCC reached a settlement in principle.

On January 11, 2018, CL&P filed a distribution rate case settlement agreement for approval by PURA, which included, among other things, rate increases of $97.1 million, $32.7 million and $24.7 million, effective May 1, 2018, 2019, and 2020, respectively, an authorized regulatory ROE of 9.25 percent, 53 percent common equity in CL&P's capital structure, and a new capital tracker through 2020 for capital additions, system resiliency, and grid modernization. The rate increases associated with the settlement agreement will be reduced by the impact of the decrease in the federal corporate income tax rate, as part of the "Tax Cuts and Jobs Act", which we currently estimate to average approximately $45 million to $50 million per year, while amounts related to ADIT will be addressed in a separate manner. We expect to receive final approval from PURA in the second quarter of 2018.



Clean Energy RFP: On January 31, 2018, pursuant to Section 8 of Public Act 13-303, "An Act Concerning Connecticut's Clean Energy Goals," as amended by Section 10 of Public Act 17-144, "An Act Promoting the Use of Fuel Cells for Electric Distribution System Benefits and Reliability and Amending Various Energy-Related Programs and Requirements," DEP issued the Connecticut Clean Energy RFP, seeking bids from developers of qualified offshore wind, fuel cell and anaerobic digestion Class I resources. The maximum authorized procurement for qualified clean energy and RECs is 899,250 MWh per year, of which no more than 825,000 MWh per year may be provided by offshore wind, which in aggregate is the equivalent to the output of an approximate 200 MW facility. Energy deliveries under any resulting agreement must begin no earlier than July 1, 2019 and no later than December 31, 2025. The Connecticut EDC's, including CL&P, will be part of the evaluation team responsible for conducting an evaluation and ranking bids received. Eversource and Ørsted are expected to submit a bid in response to this RFP.

## Massachusetts:

NSTAR Electric Distribution Rate Case Decision: On November 30, 2017, the DPU issued its decision in the NSTAR Electric distribution rate case, which approved an annual distribution rate increase of $37 million, with rates effective February 1, 2018. On January 3, 2018, NSTAR Electric filed a motion to reflect a revenue requirement reduction of $56 million (due to the decrease in the federal corporate income tax rate, as part of the "Tax Cuts and Jobs Act"), resulting in an annual net decrease in rates of $19 million.

In addition to its decision regarding rates, the DPU approved an authorized regulatory ROE of 10 percent, the establishment of a revenue decoupling rate mechanism for the portion of the NSTAR Electric business that did not previously have a decoupling mechanism, and the implementation of an inflation-based adjustment mechanism with a five-year stay-out until January 1, 2023.

Among other items, the DPU approved the recovery of previously expensed merger-related costs over a 10-year period and the recovery of previously deferred storm costs with carrying charges at the prime rate, but disallowed certain property taxes. The rate case decision resulted in the recognition of an aggregate $44.1 million pre-tax benefit recorded in 2017.

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, Harbor Electric Energy Company, a wholly-owned subsidiary of 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.

In 2017, as a result of the settlement, NSTAR Electric expensed $4.9 million (pre-tax) of previously incurred capitalized costs associated with engineering work performed on the existing cable that will no longer be used. In addition, 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 will result in the initial $17.5 million of construction costs on the new cable to be expensed as incurred. Of this amount, NSTAR Electric expensed $11.1 million (pre-tax) of costs incurred on the new cable in 2017. Construction of the new cable is expected to be completed in 2019.

Massachusetts RFPs: On March 31, 2017, pursuant to a comprehensive energy law enacted in 2016, "An Act to Promote Energy Diversity," (the "Act") the Massachusetts EDCs, including NSTAR Electric, and the DOER issued a joint RFP for 9.45 terawatt hours of clean energy per year, such as hydropower, land-based wind or solar. The RFP seeks proposals for long-term contracts of 15 to 20 years to provide the state's EDCs with clean energy generation with a submission due date of July 27, 2017.

On January 25, 2018, the Northern Pass project was selected from the 46 proposals submitted as a winning bidder. On February 1, 2018, the NHSEC voted to deny Northern Pass' siting application. On February 14, 2018, pursuant to the NHSEC's decision, the Massachusetts EDCs, in coordination with the DOER and an independent evaluator, notified NPT that the EDCs will continue contract negotiations, with the option of discontinuing discussions and terminating its conditional selection by March 27, 2018.

On June 29, 2017, pursuant to the Act, the Massachusetts EDCs, including NSTAR Electric, and the DOER issued a joint RFP for long-term contracts for offshore wind energy projects, seeking bids for a minimum of 400 MW of offshore wind capacity. The RFP stated that bids of up to 800 MW would be considered, provided they demonstrated significant net economic benefits to customers. On December 20, 2017, Bay State Wind submitted two proposals in response to the Massachusetts clean energy RFP to the EDCs. One proposal was for 400 MW and the other was for 800 MW. The selection of the winning proposals for further negotiation of power purchase agreements with the EDCs is currently expected to occur by April 23, 2018.



## New Hampshire:

Generation Divestiture: In June 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement, under the terms of which PSNH agreed to divest its generation assets, subject to NHPUC approval. The NHPUC approval for this agreement, as well as NHPUC approval of the final divestiture plan and auction process, were received in the second half of 2016. In October 2017, PSNH entered into two Purchase and Sale Agreements ("Agreements") to sell its thermal and hydroelectric generation assets to private investors at purchase prices of $175 million and $83 million, respectively, subject to adjustments as set forth in the Agreements. The NHPUC approved the Agreements in late November 2017.

On January 10, 2018, PSNH completed the sale of its thermal generation facilities. In accordance with the Purchase and Sale 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, resulting in net proceeds of $134.1 million. We are targeting for PSNH to complete the sale of its hydroelectric generation facilities by the end of the first quarter of 2018 at a sale price of $83 million, subject to adjustment. On January 30, 2018, the NHPUC approved the issuance of rate reduction bonds up to $690 million to recover stranded costs, subject to an audit by the NHPUC Audit Staff. This order is subject to an appeal period of 30 days.

Upon completion of the divestiture, full recovery of PSNH's generation assets and transaction-related costs are expected to occur through a combination of cash flows during the remaining operating period, sales proceeds, and recovery of stranded costs via the issuance of bonds that will be secured by a non-bypassable charge or through recoveries in future rates billed to PSNH's customers.

## Legislative and Policy Matters

Federal: On December 22, 2017, the "Tax Cuts and Jobs Act" (the "Act") became law, which amended existing federal tax rules and included numerous provisions that will impact corporations. In particular, the Act reduced the federal corporate income tax rate from 35 percent to 21 percent effective January 1, 2018. See "Regulatory Developments and Rate Matters - U.S. Federal Corporate Income Taxes" in this Management's Discussion and Analysis of Financial Condition and Results of Operations, for more information.

Massachusetts: On August 11, 2017, Massachusetts issued final legislation, pursuant to Executive Order 569, which established volumetric limits on multiple greenhouse emission sources to ensure reductions are realized by deadlines established in the Massachusetts Global Warming Solutions Act enacted in 2008. Under this legislation, the initial target date for reduction in greenhouse gas emissions has been established in the year 2020. The legislation is not expected to have a material impact on the financial statements of Eversource or NSTAR Electric.

New Hampshire: On January 11, 2018, the New Hampshire Supreme Court issued a decision affirming the lower court's October 2016 decision that the Town of Bow, New Hampshire had over-assessed the value of the property owned by PSNH for the 2012 and 2013 property tax years. We estimate that the result of this decision will be approximately $7.5 million in property taxes and interest payable to PSNH. PSNH plans to account for any recovery on the same basis that the taxes were originally expensed in the respective periods covered by the decision.

## 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 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 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 earnings in the period in which the determination is made.

Unbilled Revenues: The determination of retail energy sales to residential, commercial and industrial customers is based on the reading of meters, which occurs regularly throughout the month. Billed revenues are based on these meter readings, and the majority of our recorded annual revenues is based on actual billings. Because customers are billed throughout the month based on pre-determined cycles rather than on a calendar month basis, an estimate of electricity or natural gas delivered to customers for which the customers have not yet been billed is calculated as of the balance sheet date.



Unbilled revenues represent an estimate of electricity or natural gas delivered to customers but not yet billed. Unbilled revenues are included in Operating Revenues on the statement of income and are assets on the balance sheet that are reclassified to Accounts Receivable in the following month as customers are billed. Such estimates are subject to adjustment when actual meter readings become available or when there is a change in our estimates.

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 revenues can vary significantly from period to period as a result of seasonality, weather, customer usage patterns, customer rates in effect for customer classes, and the timing of customer billing. The estimate of unbilled revenues can significantly impact the amount of revenues recorded at the operating companies that do not have a revenue decoupling mechanism. CL&P, NSTAR Electric and NSTAR Gas record a regulatory deferral to reflect the actual allowed amount of revenue associated with their respective decoupled distribution rate design.

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 this assumption, 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, 2017, our aggregate expected long-term rate-of-return assumption of 8.25 percent was used to determine our pension and PBOP expense. For the forecasted 2018 pension and PBOP expense, our expected long-term rate of return of 8.25 percent 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 2017 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, 2017, the discount rates used to determine the funded status were within a range of 3.43 percent to 3.75 percent for the Pension and SERP Plans, and within a range of 3.55 percent to 3.70 percent for the PBOP Plans. As of December 31, 2016, the discount rates used were within a range of 4.01 percent to 4.33 percent for the Pension and SERP Plans, and 4.21 percent for the PBOP Plan. The decrease in the discount rates used to calculate the funded status resulted in an increase to the Pension and PBOP Plans' liability of approximately $390 million and $641 million, respectively, as of December 31, 2017.

Effective January 1, 2016, we elected to transition the discount rate to the spot rate methodology from the yield-curve approach 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. Historically, these components were estimated using the same weighted-average discount rate as for the funded status. The discount rates used to estimate the 2017 service costs were within a range of 3.58 percent to 3.90 percent for the Pension and SERP Plans, and 4.64 percent for the PBOP Plans. The discount rates used to estimate the 2017 interest costs were within a range of 3.20 percent and 3.36 percent for the Pension and SERP Plans, and 3.48 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 2017, the IRS issued a revised mortality table used for determining lump sum payments from the Pension Plan, resulting in an increase to the liability of approximately $38 million. Also in 2017, a revised scale for the mortality table was released, having the effect of decreasing the estimate of benefits to be provided to plan participants. The impact of the adoption of the revised mortality scale resulted in a decrease of approximately $26 million and $4 million for the Pension and PBOP Plans, respectively, as of December 31, 2017.

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, 2017, the compensation/progression rate used to determine the funded status was within a range of 3.50 percent to 4.00 percent. As of December 31, 2016, this rate was 3.50 percent.

Health Care Cost: In August 2016, we amended the Eversource PBOP Plan to standardize benefit design and make benefit changes. As a result, this plan is no longer subject to health care cost trends.

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 differences between assumptions and actual information or updated assumptions. Pre-tax net periodic benefit expense for the Pension and SERP Plans was $64.9 million, $71.9 million and $134.7 million for the years ended December 31, 2017, 2016 and 2015, respectively. The pre-tax net periodic PBOP cost is income of $39.6 million and $17.9 million for the years ended December 31, 2017 and 2016, respectively, and expense of $2.4 million for the year ended December 31, 2015.

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 unrecognized actuarial gains and losses.



Forecasted Expenses and Expected Contributions: We estimate that the expense for the Pension and SERP Plans will be approximately $45 million and income for the PBOP Plans will be approximately $45 million in 2018. 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 $235.2 million to the Pension Plans in 2017. We currently estimate contributing approximately $180 million to the Pension Plans in 2018.

For the PBOP Plans, it is our policy to fund the PBOP Plans annually through tax deductible contributions to external trusts. We contributed $7.6 million to the PBOP Plans in 2017. We currently estimate contributing $10 million to the PBOP Plans in 2018.

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

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">Increase in Pension Plan Cost</td><td colspan="3">Increase in PBOP Plan Cost</td></tr><tr><td colspan="6">As of December 31,</td></tr><tr><td>Assumption Change</td><td colspan="6">2017</td></tr><tr><td>Eversource</td><td>2017</td><td>2016</td><td>2017</td><td>2016</td><td>2017</td><td>2016</td></tr><tr><td>Lower expected long-term rate of return</td><td>$     20.4</td><td>$     19.5</td><td>$     4.1</td><td>$     3.9</td><td></td><td></td></tr><tr><td>Lower discount rate</td><td>19.7</td><td>20.7</td><td>3.6</td><td>3.9</td><td></td><td></td></tr><tr><td>Higher compensation rate</td><td>9.3</td><td>10.2</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. On December 4, 2017, we completed the acquisition of Aquarion, resulting in the addition of $0.9 billion of goodwill. As of December 31, 2017, a total of $4.4 billion of goodwill is recorded on our balance sheet. We have identified our reporting units for purposes of allocating and testing goodwill as Electric Distribution, Electric Transmission, Natural Gas Distribution and Water. These reporting units are consistent with our operating segments underlying our reportable segments. 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 reporting unit was created upon completion of the acquisition of Aquarion and includes its water utility businesses. As of December 31, 2017, 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.

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, 2017 for the Electric Distribution, Electric Transmission and Natural Gas 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 2017 goodwill impairment test resulted in a conclusion that goodwill is not impaired and no reporting unit is at risk of a goodwill impairment.

Long-Lived Assets: Impairment evaluations of long-lived assets, including property, plant and equipment and strategic, infrastructure and other investments, 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. As of December 31, 2017, we did not identify any impairment indicators for our long-lived assets. If events or changes in circumstances indicate the carrying value of a long-lived asset may not be recoverable, we would perform an impairment analysis. An impairment analysis would consist of two steps: first, the estimated undiscounted future cash flows attributable to the asset would be compared with the carrying value of the asset, and second, if the carrying value is greater than the undiscounted future cash flows, an impairment charge would be recognized equal to the amount by which the carrying value of the asset exceeds its estimated fair value.

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. Once a tax position meets the recognition threshold, the tax benefit is measured using a cumulative probability assessment. Assigning probabilities in measuring a recognized tax position and evaluating new information or events in subsequent periods requires significant judgment and could change previous conclusions used to measure the tax position estimate. New information or events may include tax examinations or appeals (including information gained from those examinations), developments in case law, settlements of tax positions, changes in tax law and regulations, rulings by taxing authorities and statute of limitation expirations. Such information or events may have a significant impact on our financial position, results of operations and cash flows.

On December 22, 2017, the "Tax Cuts and Jobs Act" (the "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 will be (1) the benefit of incurring a lower federal income tax expense, which we expect to be passed back to customers, and (2) the provisional regulated excess ADIT liabilities that we expect to benefit our customers in future periods, which were estimated to be approximately $2.9 billion and recognized as regulatory liabilities as of December 31, 2017.

We will continue to evaluate the impacts of the Act, which will vary depending on the ultimate amount and timing of when certain income tax benefits will benefit our customers, and will vary by jurisdiction. Although the impacts could not be finalized upon the issuance of this combined Annual Report on Form 10-K, reasonable provisional estimates were recognized as of December 31, 2017. In accordance with SEC Staff Accounting Bulletin No. 118 ("SAB 118"), additional re-measurement may occur based on final analyses, computations, technical corrections, or other forms of guidance issued from regulatory agencies or commissions. While we believe the impacts of the Act were appropriately accounted for in accordance with applicable authoritative guidance, the ultimate outcome may be different from the provisional estimates recorded, and those differences may materially impact our future statement of financial position, results of operations, and cash flows.

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. Adjustments made 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 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. As assessments on these sites are performed, we may receive new information to be considered in our estimates related to the extent and nature of the contamination and the costs of required remediation.

Our estimates also incorporate currently enacted state and federal environmental laws and regulations and data released by the EPA and other organizations. The estimates associated with each possible action plan are judgmental in nature partly because there are usually several different remediation options from which to choose. 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, to our investments in our Pension and PBOP Plans, and to nonfinancial assets such as goodwill and AROs. This guidance was also applied in estimating the fair value of preferred stock and long-term debt.

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.



Accounting Standards: For information regarding new accounting standards, see Note 1D, "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, 2017, is summarized annually through 2022 and thereafter as follows:

<table><tr><td colspan="9">Eversource</td></tr><tr><td>(Millions of Dollars)</td><td>2018</td><td>2019</td><td>2020</td><td>2021</td><td>2022</td><td>Thereafter</td><td>Total</td><td></td></tr><tr><td>Long-term debt maturities (a)</td><td>$ 961.0</td><td>$ 801.0</td><td>$ 296.1</td><td>$ 922.8</td><td>$ 1,188.9</td><td>$ 7,643.1</td><td>$ 11,812.9</td><td></td></tr><tr><td>Estimated interest payments on existing debt (b)</td><td>446.4</td><td>417.4</td><td>378.9</td><td>361.5</td><td>328.9</td><td>2,994.5</td><td>4,927.6</td><td></td></tr><tr><td>Capital leases (c)</td><td>2.9</td><td>3.3</td><td>3.3</td><td>2.8</td><td>1.3</td><td>2.5</td><td>16.1</td><td></td></tr><tr><td>Operating leases (d)</td><td>13.2</td><td>11.4</td><td>10.0</td><td>8.9</td><td>7.4</td><td>19.7</td><td>70.6</td><td></td></tr><tr><td>Funding of pension obligations (d)(e)</td><td>180.0</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>180.0</td><td></td></tr><tr><td>Funding of PBOP obligations (d)(e)</td><td>10.0</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>10.0</td><td></td></tr><tr><td>Estimated future annual long-term contractual costs (f)</td><td>599.0</td><td>578.2</td><td>542.8</td><td>497.2</td><td>459.5</td><td>2,869.4</td><td>5,546.1</td><td></td></tr><tr><td>Total (g)</td><td>$ 2,212.5</td><td>$ 1,811.3</td><td>$ 1,231.1</td><td>$ 1,793.2</td><td>$ 1,986.0</td><td>$ 13,529.2</td><td>$ 22,563.3</td><td></td></tr></table>

<table><tr><td>(Millions of Dollars)</td><td>2018</td><td>2019</td><td>2020</td><td>2021</td><td>2022</td><td>Thereafter</td><td>Total</td></tr><tr><td>Long-term debt maturities (a)</td><td>$ 300.0</td><td>$ 250.0</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ 2,515.3</td><td>$ 3,065.3</td></tr><tr><td>Estimated interest payments on existing debt (b)</td><td>137.1</td><td>121.7</td><td>114.8</td><td>114.8</td><td>114.8</td><td>1,462.8</td><td>2,066.0</td></tr><tr><td>Capital leases (c)</td><td>2.0</td><td>2.0</td><td>2.0</td><td>1.4</td><td>—</td><td>—</td><td>7.4</td></tr><tr><td>Operating leases (d)</td><td>1.8</td><td>1.5</td><td>1.3</td><td>1.1</td><td>1.0</td><td>1.0</td><td>7.7</td></tr><tr><td>Funding of pension obligations (d)(e)</td><td>82.0</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>82.0</td></tr><tr><td>Estimated future annual long-term contractual costs (f)</td><td>177.9</td><td>175.4</td><td>198.2</td><td>187.8</td><td>175.6</td><td>836.9</td><td>1,751.8</td></tr><tr><td>Total (g)</td><td>$ 700.8</td><td>$ 550.6</td><td>$ 316.3</td><td>$ 305.1</td><td>$ 291.4</td><td>$ 4,816.0</td><td>$ 6,980.2</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. Estimated interest payments on floating-rate debt are calculated by multiplying the end of 2017 floating-rate reset on the debt by its scheduled notional amount outstanding for the period of measurement. This same rate is then assumed for the remaining life of the debt.

(c) The capital lease obligations include interest.

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

(e) These amounts represent expected pension and PBOP contributions for 2018. 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 6, "Asset Retirement Obligations," Note 7, "Short-Term Debt," Note 8, "Long-Term Debt," Note 9A, "Employee Benefits - Pension Benefits and Postretirement Benefits Other Than Pensions," Note 11, "Commitments and Contingencies," and Note 13, "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, 2017 and 2016 included in this Annual Report on Form 10-K:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td><td colspan="2">Increase/(Decrease)</td></tr><tr><td>Operating Revenues</td><td>$ 7,752.0</td><td>$ 7,639.1</td><td>$</td><td>112.9</td></tr><tr><td>Operating Expenses:</td><td></td><td></td><td></td><td></td></tr><tr><td>Purchased Power, Fuel and Transmission</td><td>2,535.3</td><td>2,500.8</td><td></td><td>34.5</td></tr><tr><td>Operations and Maintenance</td><td>1,277.1</td><td>1,323.5</td><td></td><td>(46.4)</td></tr><tr><td>Depreciation</td><td>773.8</td><td>715.5</td><td></td><td>58.3</td></tr><tr><td>Amortization of Regulatory Assets, Net</td><td>90.0</td><td>71.7</td><td></td><td>18.3</td></tr><tr><td>Energy Efficiency Programs</td><td>480.8</td><td>533.7</td><td></td><td>(52.9)</td></tr><tr><td>Taxes Other Than Income Taxes</td><td>676.8</td><td>634.0</td><td></td><td>42.8</td></tr><tr><td>Total Operating Expenses</td><td>5,833.8</td><td>5,779.2</td><td></td><td>54.6</td></tr><tr><td>Operating Income</td><td>1,918.2</td><td>1,859.9</td><td></td><td>58.3</td></tr><tr><td>Interest Expense</td><td>421.8</td><td>401.0</td><td></td><td>20.8</td></tr><tr><td>Other Income, Net</td><td>78.0</td><td>45.9</td><td></td><td>32.1</td></tr><tr><td>Income Before Income Tax Expense</td><td>1,574.4</td><td>1,504.8</td><td></td><td>69.6</td></tr><tr><td>Income Tax Expense</td><td>578.9</td><td>555.0</td><td></td><td>23.9</td></tr><tr><td>Net Income</td><td>995.5</td><td>949.8</td><td></td><td>45.7</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>7.5</td><td>7.5</td><td></td><td>—</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 988.0</td><td>$ 942.3</td><td>$</td><td>45.7</td></tr></table>

## Operating Revenues

A summary of our Operating Revenues by segment 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>2017</td><td>2016</td><td colspan="2">Increase/(Decrease)</td></tr><tr><td>Electric Distribution</td><td>$ 5,542.9</td><td>$ 5,594.3</td><td>$</td><td>(51.4)</td></tr><tr><td>Natural Gas Distribution</td><td>947.3</td><td>857.7</td><td></td><td>89.6</td></tr><tr><td>Electric Transmission</td><td>1,301.7</td><td>1,210.0</td><td></td><td>91.7</td></tr><tr><td>Other and Eliminations</td><td>(39.9)</td><td>(22.9)</td><td></td><td>(17.0)</td></tr><tr><td>Total Operating Revenues</td><td>$ 7,752.0</td><td>$ 7,639.1</td><td>$</td><td>112.9</td></tr></table>

A summary of our retail electric GWh sales volumes and our firm natural gas sales volumes in MMcf and percentage changes was as follows:

<table><tr><td rowspan="3"></td><td colspan="4">Electric</td><td colspan="4">Firm Natural Gas</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>2017</td><td>2016</td><td>Decrease</td><td>Percent</td><td>2017</td><td>2016</td><td>Increase</td><td>Percent</td></tr><tr><td>Traditional</td><td>27,855</td><td>28,479</td><td>(624)</td><td>(2.2)%</td><td>46,957</td><td>45,314</td><td>1,643</td><td>3.6%</td></tr><tr><td>Decoupled and Natural Gas Special Contracts</td><td>24,391</td><td>25,163</td><td>(772)</td><td>(3.1)%</td><td>54,069</td><td>52,728</td><td>1,341</td><td>2.5%</td></tr><tr><td>Total Sales Volumes</td><td>52,246</td><td>53,642</td><td>(1,396)</td><td>(2.6)%</td><td>101,026</td><td>98,042</td><td>2,984</td><td>3.0%</td></tr></table>

Fluctuations in sales volumes at certain of the electric and natural gas utilities impact earnings ("Traditional" in the table above). Fluctuations in CL&P's, NSTAR Electric's (for a portion of its sales volumes as of December 31, 2017) and NSTAR Gas' sales volumes do not impact the level of base distribution revenue realized or earnings due to the commission-approved revenue decoupling mechanisms ("Decoupled and Natural Gas Special Contracts" in the table above). The revenue decoupling mechanisms permit recovery of a base amount of distribution revenues and breaks the relationship between sales volumes and revenues recognized. Effective February 1, 2018, all of NSTAR Electric's distribution revenues were decoupled as a result of the DPU-approved rate case decision.

Operating Revenues, which primarily consist of base electric and natural gas distribution revenues and tracked revenues further described below, increased by $112.9 million in 2017, as compared to 2016.

Base electric and natural gas distribution revenues: Base electric distribution segment revenues, excluding LBR, decreased $12.3 million in 2017, as compared to 2016, due primarily to a decrease in sales volumes driven by the mild summer weather in 2017 at our non-decoupled electric companies. LBR increased $13.0 million in 2017, as compared to 2016. Effective February 1, 2018, NSTAR Electric no longer has an LBR mechanism. Base natural gas distribution revenues increased $2.9 million in 2017, as compared to 2016. The impact of higher firm natural gas sales volumes, which was driven by colder winter weather in the fourth quarter of 2017, was partially offset by lower demand revenues in Connecticut driven by lower peak usage in 2017, as compared to 2016.



Tracked distribution revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through regulatory commission-approved cost tracking mechanisms and therefore, have no impact on earnings. Costs recovered through cost tracking mechanisms include energy supply procurement and other energy-related costs for our electric and natural gas customers, retail transmission charges, energy efficiency program costs, net metering for distributed generation and restructuring and stranded cost recovery revenues. In addition, certain tracked revenues include incentives earned and carrying charges that are billed in rates to customers.

Tracked natural gas distribution segment revenues increased as a result of an increase in natural gas supply costs ($68.7 million) and an increase in energy efficiency program revenues ($18.1 million). Tracked electric distribution revenues decreased as a result of a decrease in electric energy supply costs ($21.7 million), driven by decreased average retail prices and lower sales volumes, a decrease in retail electric transmission charges ($14.8 million), a decrease in transition and stranded cost recovery revenues ($46.2 million), a decrease in pension rate adjustment mechanisms ($21.6 million), a decrease in revenues related to the timing of the sale of PSNH's RECs ($16.3 million), and a decrease in energy efficiency program revenues ($10.4 million). Partially offsetting these decreases were increases in tracked electric distribution revenues related to federally-mandated congestion charges ($30.1 million), net metering revenues ($29.8 million) and revenues related to renewable energy requirements ($41.9 million).

Electric transmission revenues: The electric transmission segment revenues increased by $91.7 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Other: Other revenues decreased due primarily to the sale of Eversource's unregulated telecommunication business on December 31, 2016 ($20.0 million), partially offset by the addition of Aquarion revenues due to the acquisition on December 4, 2017 ($15.9 million).

Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity and natural gas on behalf of our customers. These energy supply costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power, Fuel and Transmission expense increased in 2017, as compared to 2016, due primarily to the following:

<table><tr><td>(Millions of Dollars)</td><td>(Decrease)/Increase</td></tr><tr><td>Electric Distribution</td><td>$ (68.9)</td></tr><tr><td>Natural Gas Distribution</td><td>59.5</td></tr><tr><td>Transmission</td><td>43.9</td></tr><tr><td>Total Purchased Power, Fuel and Transmission</td><td>$ 34.5</td></tr></table>

The decrease in purchased power expense at the electric distribution business in 2017, as compared to 2016, was driven primarily by lower prices associated with the procurement of energy supply and lower sales volumes. The increase in purchased power expense at the natural gas distribution business was due to higher average natural gas prices and higher sales volumes. The increase in transmission costs in 2017, as compared to 2016, was primarily the result of an increase in costs billed by ISO-NE that support regional grid investment, and Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network. This was partially offset by a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.

Operations and Maintenance expense includes tracked costs and costs that are part of base electric and natural gas distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense decreased in 2017, as compared to 2016, due primarily to the following:

<table><tr><td>(Millions of Dollars)</td><td>Increase/(Decrease)</td></tr><tr><td>Base Electric Distribution:</td><td></td></tr><tr><td>Employee-related expenses, including labor and benefits</td><td>$ (47.4)</td></tr><tr><td>Bad debt expense</td><td>(14.5)</td></tr><tr><td>Shared corporate costs (including computer software depreciation at Eversource Service)</td><td>24.2</td></tr><tr><td>Boston Harbor civil action settlement charges</td><td>16.0</td></tr><tr><td>Other non-tracked operations and maintenance</td><td>7.4</td></tr><tr><td>Total Base Electric Distribution</td><td>(14.3)</td></tr><tr><td>Base Natural Gas Distribution</td><td>3.7</td></tr><tr><td>Tracked costs (Electric Distribution, Electric Transmission and Natural Gas Distribution):</td><td></td></tr><tr><td>Absence in 2017 of earnings benefit related to merger-related costs allowed for recovery through transmission rates</td><td>27.5</td></tr><tr><td>Other tracked operations and maintenance</td><td>(15.4)</td></tr><tr><td>Total Tracked costs (Electric Distribution, Electric Transmission and Natural Gas Distribution)</td><td>12.1</td></tr><tr><td>Other and eliminations:</td><td></td></tr><tr><td>Merger-related costs allowed for recovery through NSTAR Electric distribution rates as a result of the November 30, 2017</td><td></td></tr><tr><td>DPU distribution rate case decision (earnings benefit)</td><td>(30.5)</td></tr><tr><td>Addition of Aquarion operations and maintenance expenses due to acquisition on December 4, 2017</td><td>7.2</td></tr><tr><td>Eversource Parent and Other Companies - other operations and maintenance</td><td>8.2</td></tr><tr><td>Eliminations</td><td>(32.8)</td></tr><tr><td>Total Operations and Maintenance</td><td>$ (46.4)</td></tr></table>



Depreciation expense increased in 2017, as compared to 2016, due primarily to higher utility plant in service balances.

Amortization of Regulatory Assets, Net expense includes the deferral of energy supply and energy-related costs included in certain regulatory-approved tracking mechanisms, and the amortization of certain costs. The deferral adjusts expense to match the corresponding revenues. Amortization of Regulatory Assets, Net increased in 2017, as compared to 2016, due primarily to the deferral of energy supply and energy-related costs which can fluctuate from period to period based on the timing of costs incurred and the related rate changes to recover these costs. Energy supply and energy-related costs at the electric and natural gas companies are recovered from customers in rates and have no impact on earnings.

Energy Efficiency Programs expense decreased in 2017, as compared to 2016, due primarily to a State of Connecticut policy change impacting CL&P requiring the remittance of $25.4 million of 2017 energy efficiency funds to the State (resulting in these costs being classified as Taxes Other than Income Taxes), and the deferral adjustment at NSTAR Electric. The deferral adjustment reflects the actual costs of energy efficiency programs compared to the estimated amounts billed to customers. The deferral adjusts costs incurred to match energy efficiency revenue billed to customers and the timing of the recovery of energy efficiency costs. The costs for various state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates and have no impact on earnings.

Taxes Other Than Income Taxes expense increased in 2017, as compared to 2016, due primarily to a State of Connecticut policy change requiring $25.4 million of 2017 CL&P energy efficiency costs to be remitted to the State of Connecticut that is included in Taxes Other than Income Taxes, an increase in property taxes as a result of higher utility plant balances, partially offset by a decrease in gross earnings taxes. Gross earnings taxes are recovered from customers in rates and have no impact on earnings.

Interest Expense increased in 2017, as compared to 2016, due primarily to an increase in interest on long-term debt ($30.3 million) as a result of new debt issuances and an increase in interest on notes payable ($5.1 million), partially offset by a decrease in regulatory deferrals, primarily at NSTAR Electric, which decreased interest expense ($14.7 million) due primarily to the November 30, 2017 NSTAR Electric DPU distribution rate case decision which allowed for a higher rate on carrying charges for past storm costs.

Other Income, Net increased in 2017, as compared to 2016, due primarily to increased gains on investments ($27.2 million), primarily related to Eversource's investment in a renewable energy fund, changes in the market value related to deferred compensation plans ($8.3 million) and higher AFUDC related to equity funds ($8.2 million). Partially offsetting these favorable impacts was the absence in 2017 of a gain on the sale of an unregulated business in 2016 ($11.8 million) and lower interest income ($3.3 million).

Income Tax Expense increased in 2017, as compared to 2016, due primarily to higher pre-tax earnings ($29.1 million), lower excess tax benefit ($16.2 million), the absence of tax credits in 2017 ($3.5 million), and the impact from federal tax rate change ($0.5 million), partially offset by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($11.4 million), the sale of an unregulated business in 2016 ($10.2 million), and lower state taxes ($3.8 million).



## 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, 2016 and 2015 included in this Annual Report on Form 10-K:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">For the Years Ended December 31,</td></tr><tr><td>2016</td><td>2015</td><td>Increase/(Decrease)</td><td>Percent</td><td></td></tr><tr><td>Operating Revenues</td><td>$ 7,639.1</td><td>$ 7,954.8</td><td>$ (315.7)</td><td>(4.0)%</td><td></td></tr><tr><td>Operating Expenses:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Purchased Power, Fuel and Transmission</td><td>2,500.8</td><td>3,086.9</td><td>(586.1)</td><td>(19.0)</td><td></td></tr><tr><td>Operations and Maintenance</td><td>1,323.5</td><td>1,329.3</td><td>(5.8)</td><td>(0.4)</td><td></td></tr><tr><td>Depreciation</td><td>715.5</td><td>665.9</td><td>49.6</td><td>7.4</td><td></td></tr><tr><td>Amortization of Regulatory Assets, Net</td><td>71.7</td><td>22.3</td><td>49.4</td><td>(a)</td><td></td></tr><tr><td>Energy Efficiency Programs</td><td>533.7</td><td>495.7</td><td>38.0</td><td>7.7</td><td></td></tr><tr><td>Taxes Other Than Income Taxes</td><td>634.0</td><td>590.5</td><td>43.5</td><td>7.4</td><td></td></tr><tr><td>Total Operating Expenses</td><td>5,779.2</td><td>6,190.6</td><td>(411.4)</td><td>(6.6)</td><td></td></tr><tr><td>Operating Income</td><td>1,859.9</td><td>1,764.2</td><td>95.7</td><td>5.4</td><td></td></tr><tr><td>Interest Expense</td><td>401.0</td><td>372.4</td><td>28.6</td><td>7.7</td><td></td></tr><tr><td>Other Income, Net</td><td>45.9</td><td>34.2</td><td>11.7</td><td>34.2</td><td></td></tr><tr><td>Income Before Income Tax Expense</td><td>1,504.8</td><td>1,426.0</td><td>78.8</td><td>5.5</td><td></td></tr><tr><td>Income Tax Expense</td><td>555.0</td><td>540.0</td><td>15.0</td><td>2.8</td><td></td></tr><tr><td>Net Income</td><td>949.8</td><td>886.0</td><td>63.8</td><td>7.2</td><td></td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>7.5</td><td>7.5</td><td>—</td><td>—</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 942.3</td><td>$ 878.5</td><td>$ 63.8</td><td>7.3 %</td><td></td></tr></table>

(a) Percent greater than 100 not shown as it is not meaningful.

## Operating Revenues

A summary of our Operating Revenues by segment 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>2016</td><td>2015</td><td>Increase/(Decrease)</td><td>Percent</td></tr><tr><td>Electric Distribution</td><td>$ 5,594.3</td><td>$ 5,903.6</td><td>$ (309.3)</td><td>(5.2)%</td></tr><tr><td>Natural Gas Distribution</td><td>857.7</td><td>995.5</td><td>(137.8)</td><td>(13.8)</td></tr><tr><td>Electric Transmission</td><td>1,210.0</td><td>1,069.1</td><td>140.9</td><td>13.2</td></tr><tr><td>Other and Eliminations</td><td>(22.9)</td><td>(13.4)</td><td>(9.5)</td><td>70.9</td></tr><tr><td>Total Operating Revenues</td><td>$ 7,639.1</td><td>$ 7,954.8</td><td>$ (315.7)</td><td>(4.0)%</td></tr></table>

A summary of our retail electric GWh sales volumes and our firm natural gas sales volumes in MMcf were as follows:

<table><tr><td rowspan="2"></td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2016</td><td>2015</td><td>Decrease</td><td>Percent</td></tr><tr><td>Electric</td><td></td><td></td><td></td><td></td></tr><tr><td>Traditional</td><td>28,479</td><td>28,982</td><td>(503)</td><td>(1.7)%</td></tr><tr><td>Decoupled</td><td>25,163</td><td>25,634</td><td>(471)</td><td>(1.8)</td></tr><tr><td>Total Electric</td><td>53,642</td><td>54,616</td><td>(974)</td><td>(1.8)%</td></tr><tr><td>Firm Natural Gas</td><td></td><td></td><td></td><td></td></tr><tr><td>Traditional</td><td>45,314</td><td>47,600</td><td>(2,286)</td><td>(4.8)%</td></tr><tr><td>Decoupled and Special Contracts</td><td>52,728</td><td>55,399</td><td>(2,671)</td><td>(4.8)</td></tr><tr><td>Total Firm Natural Gas</td><td>98,042</td><td>102,999</td><td>(4,957)</td><td>(4.8)%</td></tr></table>

Operating Revenues, which primarily consist of base electric and natural gas distribution revenues and tracked revenues further described below, decreased by $315.7 million in 2016, as compared to 2015.

Base electric and natural gas distribution revenues: Base electric distribution segment revenues increased by $19.9 million due primarily to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates at CL&P ($26.1 million) and the absence of a required ROE reduction in 2015, as stipulated in the PURA 2014 rate case decision, at CL&P ($4 million). This increase was partially offset by the absence of the benefit recognized in 2015 in Operating Revenues due to the PURA ADIT settlement agreement. In addition, traditional electric base distribution revenues decreased $10.1 million due to a 1.7 percent decrease in non-decoupled retail electric sales volumes due primarily to increased customer energy conservation efforts, partly offset by PSNH distribution rate increases effective July 1, 2015 and July 1, 2016.



Contributing to the decrease in Operating Revenues in 2016 was the absence of an $11 million benefit related to the Comprehensive Settlement Agreement associated with the recovery of LBR related to 2009 through 2011 energy efficiency programs recorded at NSTAR Electric in 2015.

Firm natural gas base distribution segment revenues increased $11.7 million due primarily to the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016, partially offset by a 4.8 percent decrease in traditional firm natural gas sales volumes as a result of warmer than normal weather experienced in the first quarter of 2016, as compared to much colder than normal temperatures in 2015.

Fluctuations in CL&P's, NSTAR Electric's and NSTAR Gas' sales volumes do not impact the level of base distribution revenue realized or earnings due to their respective regulatory commission approved revenue decoupling mechanisms. The revenue decoupling mechanisms permit recovery of a base amount of distribution revenues and break the relationship between sales volumes and revenues recognized. Revenue decoupling mechanisms result in the recovery of our approved base distribution revenue requirements.

Tracked distribution revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through regulatory commission-approved cost tracking mechanisms and therefore have no impact on earnings. Costs recovered through cost tracking mechanisms include energy supply procurement costs and other energy-related costs for our electric and natural gas customers, retail transmission charges, energy efficiency program costs, and restructuring and stranded cost recovery revenues. In addition, tracked revenues include certain incentives earned and carrying charges. Tracked electric distribution segment revenues decreased as a result of decreases in energy supply costs (625.2 million), driven by decreased average retail rates and lower sales volumes, partially offset by an increase in retail electric transmission charges (84.6 million), an increase in federally mandated congestion charges (103.0 million), an increase in energy efficiency program revenues (51.7 million), an increase in stranded cost recovery charges (39.2 million) and an increase in net metering for distributed generation revenues (34.0 million). In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P's calculated rate base increased, providing an increase to distribution revenues that positively impacted earnings by 23.2 million.

In 2016, tracked natural gas distribution segment revenues decreased as a result of decreases in natural gas supply costs (125.2 million) driven by decreased average rates and lower sales volumes, and a decrease in energy efficiency program revenues (22.7 million).

Electric transmission revenues: The electric transmission segment revenues increased by $140.9 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure and the absence in 2016 of a $20 million reserve charge recorded in 2015 associated with the March 2015 FERC ROE order.

Other: Other revenues decreased due primarily to the sale of Eversource's unregulated contracting business on April 13, 2015 ($11.4 million).

Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity and natural gas on behalf of our customers. These energy supply costs are recovered from customers in rates through cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power, Fuel and Transmission expense decreased in 2016, as compared to 2015, due primarily to the following:

<table><tr><td>(Millions of Dollars)</td><td>(Decrease)/Increase</td></tr><tr><td>Electric Distribution</td><td>$ (625.9)</td></tr><tr><td>Natural Gas Distribution</td><td>(130.3)</td></tr><tr><td>Transmission</td><td>170.1</td></tr><tr><td>Total Purchased Power, Fuel and Transmission</td><td>$ (586.1)</td></tr></table>

The decrease in purchased power expense at the electric distribution business was driven by lower prices associated with the procurement of energy supply, lower sales volumes, and a decrease in the amount of electricity generated by PSNH facilities in 2016, as compared to 2015. The decrease in purchased power expense at the natural gas distribution business was due to lower sales volumes and lower average natural gas prices. The increase in transmission costs was primarily the result of an increase in costs billed by ISO-NE that support regional grid investment.



Operations and Maintenance expense includes tracked costs and costs that are part of base electric and natural gas distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense decreased in 2016, as compared to 2015, due primarily to the following:

<table><tr><td>(Millions of Dollars)</td><td>Increase/(Decrease)</td></tr><tr><td>Base Electric Distribution:</td><td></td></tr><tr><td>Absence of 2015 resolution of basic service bad debt adder mechanism at NSTAR Electric</td><td>$ 24.2</td></tr><tr><td>Absence of 2015 regulatory proceedings benefiting NSTAR Electric</td><td>10.5</td></tr><tr><td>Employee-related expenses, including labor and benefits</td><td>(27.0)</td></tr><tr><td>Storm restoration costs</td><td>15.0</td></tr><tr><td>Write-off of software design costs</td><td>9.2</td></tr><tr><td>Other operations and maintenance</td><td>14.1</td></tr><tr><td>Total Base Electric Distribution</td><td>46.0</td></tr><tr><td>Total Base Natural Gas Distribution:</td><td></td></tr><tr><td>Employee-related expenses, including labor and benefits</td><td>(15.5)</td></tr><tr><td>Other operations and maintenance</td><td>8.2</td></tr><tr><td>Total Base Natural Gas Distribution</td><td>(7.3)</td></tr><tr><td>Tracked costs (Electric Distribution, Electric Transmission and Natural Gas Distribution):</td><td></td></tr><tr><td>Merger-related costs allowed for recovery through transmission rates (earnings benefit)</td><td>(27.5)</td></tr><tr><td>Other tracked operations and maintenance</td><td>41.8</td></tr><tr><td>Total Tracked costs (Electric Distribution, Electric Transmission and Natural Gas Distribution)</td><td>14.3</td></tr><tr><td>Other and eliminations:</td><td></td></tr><tr><td>Integration costs</td><td>(27.2)</td></tr><tr><td>Absence of Eversource&#x27;s unregulated electrical contracting business due to sale in April 2015, net</td><td>(13.9)</td></tr><tr><td>Eversource Parent and Other Companies</td><td>(2.8)</td></tr><tr><td>Eliminations</td><td>(14.9)</td></tr><tr><td>Total Operations and Maintenance</td><td>$ (5.8)</td></tr></table>

Depreciation expense increased in 2016, as compared to 2015, due primarily to higher utility plant in service balances.

Amortization of Regulatory Assets, Net expense includes the deferral of energy supply and energy-related costs included in certain regulatory-approved tracking mechanisms and the amortization of certain costs. The deferral adjusts expense to match the corresponding revenues. Amortization of Regulatory Assets, Net increased in 2016, as compared to 2015, due primarily to the deferral of energy supply and energy-related costs which can fluctuate from period to period based on the timing of costs incurred and the related rate changes to recover these costs. Energy supply and energy-related costs at CL&P, NSTAR Electric and PSNH, which are the primary drivers in amortization, are recovered from customers in rates and have no impact on earnings. The increase in Amortization of Regulatory Assets, Net for the year ended December 31, 2016 also includes the absence in 2016 of the $11.7 million benefit recorded in 2015 at NSTAR Electric in connection with the Comprehensive Settlement Agreement.

Energy Efficiency Programs expense increased in 2016, as compared to 2015, due primarily to deferral adjustments at NSTAR Electric, partially offset by deferral adjustments for the natural gas businesses, which reflect the actual costs of energy efficiency programs compared to the estimated amounts billed to customers, and the timing of the recovery of energy efficiency costs incurred in accordance with the three-year program guidelines established by the DPU. The deferrals adjust expense to match the energy efficiency programs revenue. The costs for various state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates and have no impact on earnings.

Taxes Other Than Income Taxes expense increased in 2016, as compared to 2015, due primarily to an increase in property taxes as a result of higher utility plant balances and an increase in gross earnings taxes. Gross earnings taxes are recovered from customers in rates and have no impact on earnings.

Interest Expense increased in 2016, as compared to 2015, due primarily to an increase in interest on long-term debt ($33.8 million) as a result of new debt issuances and an increase in interest on notes payable ($2.2 million), partially offset by a decrease in regulatory deferrals which decreased interest expense ($5.5 million).

Other Income, Net increased in 2016, as compared to 2015, due primarily to higher equity AFUDC amounts ($7.4 million), higher gains related to the sales of unregulated businesses ($9.4 million) and an increase in interest income ($4.1 million). Partially offsetting these favorable impacts were the market value changes related to deferred compensation plans ($9.6 million).

Income Tax Expense increased in 2016, as compared to 2015, due primarily to higher pre-tax earnings ($24.2 million), higher state taxes ($7.5 million), and the sale of an unregulated business ($10.2 million), partially offset by the excess tax benefit due to the adoption of new accounting guidance related to share based payment transactions ($19.1 million), the true-up of the return to provision impacts and a higher tax benefit from a reduction in tax reserves ($7.6 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.2 million).



## EARNINGS SUMMARY

Regulated Companies: Our electric distribution segment earnings decreased $44.3 million in 2016, as compared to 2015. The decrease was due primarily to the absence in 2016 of the resolution of NSTAR Electric's basic service bad debt adder mechanism recorded in 2015 ($14.5 million), the absence in 2016 of the favorable impact associated with the NSTAR Electric Comprehensive Settlement Agreement recorded in 2015 ($13.0 million), and higher depreciation expense. In addition, earnings decreased due to higher operations and maintenance expense (primarily related to the absence of a $6.3 million regulatory benefit related to certain uncollectible hardship accounts receivable that was recorded in 2015 at NSTAR Electric, as well as higher storm restoration costs, higher vegetation management costs and the write-off of software design costs), higher property tax expense, and lower non-decoupled retail electric sales volumes due primarily to increased customer energy conservation efforts. These unfavorable earnings impacts were partially offset by increased CL&P distribution revenues primarily as a result of higher rate base and the absence of a required ROE reduction, as stipulated in the PURA 2014 rate case decision, and higher generation earnings.

Our electric transmission segment earnings increased $66.3 million in 2016, as compared to 2015, due primarily to a higher transmission rate base as a result of increased investments in our transmission infrastructure, the FERC-allowed recovery of certain merger-related costs in 2016 ($16.5 million), and the absence in 2016 of reserve charges in 2015 associated with the FERC ROE complaint proceedings ($12.4 million).

Our natural gas distribution segment earnings increased $5.3 million in 2016, as compared to 2015, due primarily to the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016, the higher return earned on the NSTAR Gas System Enhancement Program ("GSEP") capital tracker mechanism effective in 2016, and lower operations and maintenance expense. These favorable earnings impacts were partially offset by lower non-decoupled firm natural gas sales volumes driven by the warmer than normal weather in the first quarter of 2016, as compared to the much colder than normal weather in the first quarter of 2015, higher property tax expense, and higher interest expense.

Eversource Parent and Other Companies: Eversource parent and other companies had earnings of $31.0 million in 2016, compared with a net loss of $5.5 million in 2015. The earnings increase was due primarily to lower income tax expense as a result of recognizing tax benefits from executive deferred compensation payments, which resulted from the adoption of a new accounting standard, and the absence in 2016 of integration costs, partially offset by higher interest expense.

## LIQUIDITY

Cash flows provided by operating activities totaled $2.2 billion in 2016, compared with $1.4 billion in 2015. The increase in operating cash flows was due primarily to the absence in 2016 of $302 million in payments made in 2015 to fully satisfy the obligation with the DOE for costs associated with the disposal of spent nuclear fuel and high-level radioactive waste at previously owned generation facilities. In addition, there was an increase of $226.0 million in regulatory recoveries, primarily at NSTAR Electric, due to $98.1 million of collections from customers in excess of purchased power costs, the favorable impact associated with the December 2015 legislation that extended tax bonus depreciation, which resulted in a $145.8 million decrease in income tax payments in 2016, as compared to 2015, and an increase of $55.2 million of the Yankee Companies' DOE Damages and other proceeds received in 2016, as compared to 2015. Partially offsetting these favorable impacts was the timing of collections and payments related to our working capital items.

Results of Operations 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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. 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 and directors 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 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 Enterprise Risk Management 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, 2017, approximately 98 percent of our long-term debt, including fees and interest due for CYAPC's spent nuclear fuel disposal costs, was at a fixed interest rate. The remaining long-term debt is at variable interest rates and is subject to interest rate risk that could result in earnings volatility. Assuming a one percentage point increase in our variable interest rates, annual interest expense would have increased by a pre-tax amount of $2.7 million.

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 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, 2017, our regulated companies did not hold collateral (letters of credit) from counterparties related to our standard service contracts. As of December 31, 2017, Eversource had $24.5 million of cash posted with ISO-NE related to energy transactions.

For further information on cash collateral deposited and posted with counterparties, see Note 1H, "Summary of Significant Accounting Policies - Deposits," 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
Report 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, 2017.

Management has excluded from our assessment of and conclusion on the effectiveness of internal controls over financial reporting the internal controls of Eversource Aquarion Holdings, Inc. (formerly Macquarie Utilities Inc.), acquired on December 4, 2017, which is included in the consolidated financial statements of the Company as of and for the year ended December 31, 2017, constituting 4.31% and 2.37% of total and net assets, respectively, as of December 31, 2017, and 0.20% of revenues for the year ended December 31, 2017.

February 23, 2018



## REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Trustees and Shareholders of Eversource Energy:

## Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the accompanying consolidated balance sheets of Eversource Energy and subsidiaries (the “Company”) as of December 31, 2017 and 2016, 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, 2017, and the related notes and the schedules listed in the Index at Item 15 of Part IV (collectively referred to as the “financial statements”). We also have audited the Company’s internal control over financial reporting as of December 31, 2017, 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 financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2017, in conformity with accounting principles generally accepted in the United States of America.

As discussed in Note 1, the Company acquired Macquarie Utilities Inc. on December 4, 2017.

Also, in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO.

As described in Company Report on Internal Controls Over Financial Reporting, management excluded from its assessment the internal control over financial reporting at Eversource Aquarion Holdings, Inc. (formerly Macquarie Utilities Inc.) which was acquired on December 4, 2017 and whose financial statements constitute 2.37% and 4.31% of net and total assets, respectively, and 0.20% of revenues of the consolidated financial statement amounts as of and for the year ended December 31, 2017. Accordingly, our audit did not include the internal control over financial reporting at Eversource Aquarion Holdings, Inc.

## Basis for Opinions

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

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

Our audits of the financial statements included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures to 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. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

## Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (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 23, 2018

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>2017</td><td>2016</td></tr><tr><td>ASSETS</td><td></td><td></td></tr><tr><td>Current Assets:</td><td></td><td></td></tr><tr><td>Cash and Cash Equivalents</td><td>$ 38,165</td><td>$ 30,251</td></tr><tr><td>Receivables, Net</td><td>925,083</td><td>847,301</td></tr><tr><td>Unbilled Revenues</td><td>201,361</td><td>168,490</td></tr><tr><td>Fuel, Materials, Supplies and Inventory</td><td>223,063</td><td>328,721</td></tr><tr><td>Regulatory Assets</td><td>741,868</td><td>887,625</td></tr><tr><td>Prepayments and Other Current Assets</td><td>138,009</td><td>215,284</td></tr><tr><td>Assets Held for Sale</td><td>219,550</td><td>—</td></tr><tr><td>Total Current Assets</td><td>2,487,099</td><td>2,477,672</td></tr><tr><td></td><td></td><td></td></tr><tr><td>Property, Plant and Equipment, Net</td><td>23,617,463</td><td>21,350,510</td></tr><tr><td></td><td></td><td></td></tr><tr><td>Deferred Debits and Other Assets:</td><td></td><td></td></tr><tr><td>Regulatory Assets</td><td>4,497,447</td><td>3,638,688</td></tr><tr><td>Goodwill</td><td>4,427,266</td><td>3,519,401</td></tr><tr><td>Marketable Securities</td><td>585,419</td><td>544,642</td></tr><tr><td>Other Long-Term Assets</td><td>605,692</td><td>522,260</td></tr><tr><td>Total Deferred Debits and Other Assets</td><td>10,115,824</td><td>8,224,991</td></tr><tr><td></td><td></td><td></td></tr><tr><td>Total Assets</td><td>$ 36,220,386</td><td>$ 32,053,173</td></tr><tr><td></td><td></td><td></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>$ 1,088,087</td><td>$ 1,148,500</td></tr><tr><td>Long-Term Debt - Current Portion</td><td>549,631</td><td>773,883</td></tr><tr><td>Accounts Payable</td><td>1,085,034</td><td>884,521</td></tr><tr><td>Regulatory Liabilities</td><td>128,071</td><td>146,787</td></tr><tr><td>Other Current Liabilities</td><td>738,222</td><td>684,914</td></tr><tr><td>Total Current Liabilities</td><td>3,589,045</td><td>3,638,605</td></tr><tr><td></td><td></td><td></td></tr><tr><td>Deferred Credits and Other Liabilities:</td><td></td><td></td></tr><tr><td>Accumulated Deferred Income Taxes</td><td>3,297,518</td><td>5,607,207</td></tr><tr><td>Regulatory Liabilities</td><td>3,637,273</td><td>702,255</td></tr><tr><td>Derivative Liabilities</td><td>377,257</td><td>413,676</td></tr><tr><td>Accrued Pension, SERP and PBOP</td><td>1,228,091</td><td>1,141,514</td></tr><tr><td>Other Long-Term Liabilities</td><td>1,073,501</td><td>853,260</td></tr><tr><td>Total Deferred Credits and Other Liabilities</td><td>9,613,640</td><td>8,717,912</td></tr><tr><td></td><td></td><td></td></tr><tr><td>Capitalization:</td><td></td><td></td></tr><tr><td>Long-Term Debt</td><td>11,775,889</td><td>8,829,354</td></tr><tr><td></td><td></td><td></td></tr><tr><td>Noncontrolling Interest - Preferred Stock of Subsidiaries</td><td>155,570</td><td>155,568</td></tr><tr><td></td><td></td><td></td></tr><tr><td>Equity:</td><td></td><td></td></tr><tr><td>Common Shareholders&#x27; Equity:</td><td></td><td></td></tr><tr><td>Common Shares</td><td>1,669,392</td><td>1,669,392</td></tr><tr><td>Capital Surplus, Paid In</td><td>6,239,940</td><td>6,250,224</td></tr><tr><td>Retained Earnings</td><td>3,561,084</td><td>3,175,171</td></tr><tr><td>Accumulated Other Comprehensive Loss</td><td>(66,403)</td><td>(65,282)</td></tr><tr><td>Treasury Stock</td><td>(317,771)</td><td>(317,771)</td></tr><tr><td>Common Shareholders&#x27; Equity</td><td>11,086,242</td><td>10,711,734</td></tr><tr><td>Total Capitalization</td><td>23,017,701</td><td>19,696,656</td></tr><tr><td></td><td></td><td></td></tr><tr><td>Commitments and Contingencies (Note 11)</td><td></td><td></td></tr><tr><td></td><td></td><td></td></tr><tr><td>Total Liabilities and Capitalization</td><td>$ 36,220,386</td><td>$ 32,053,173</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>2017</td><td>2016</td><td>2015</td></tr><tr><td>Operating Revenues</td><td>$ 7,751,952</td><td>$ 7,639,129</td><td>$ 7,954,827</td></tr><tr><td>Operating Expenses:</td><td></td><td></td><td></td></tr><tr><td>Purchased Power, Fuel and Transmission</td><td>2,535,271</td><td>2,500,828</td><td>3,086,905</td></tr><tr><td>Operations and Maintenance</td><td>1,277,147</td><td>1,323,549</td><td>1,329,289</td></tr><tr><td>Depreciation</td><td>773,802</td><td>715,466</td><td>665,856</td></tr><tr><td>Amortization of Regulatory Assets, Net</td><td>89,986</td><td>71,696</td><td>22,339</td></tr><tr><td>Energy Efficiency Programs</td><td>480,835</td><td>533,659</td><td>495,701</td></tr><tr><td>Taxes Other Than Income Taxes</td><td>676,757</td><td>634,072</td><td>590,573</td></tr><tr><td>Total Operating Expenses</td><td>5,833,798</td><td>5,779,270</td><td>6,190,663</td></tr><tr><td>Operating Income</td><td>1,918,154</td><td>1,859,859</td><td>1,764,164</td></tr><tr><td>Interest Expense</td><td>421,755</td><td>400,961</td><td>372,420</td></tr><tr><td>Other Income, Net</td><td>78,008</td><td>45,920</td><td>34,227</td></tr><tr><td>Income Before Income Tax Expense</td><td>1,574,407</td><td>1,504,818</td><td>1,425,971</td></tr><tr><td>Income Tax Expense</td><td>578,892</td><td>554,997</td><td>539,967</td></tr><tr><td>Net Income</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></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 987,996</td><td>$ 942,302</td><td>$ 878,485</td></tr><tr><td>Basic Earnings Per Common Share</td><td>$ 3.11</td><td>$ 2.97</td><td>$ 2.77</td></tr><tr><td>Diluted Earnings Per Common Share</td><td>$ 3.11</td><td>$ 2.96</td><td>$ 2.76</td></tr><tr><td>Weighted Average Common Shares Outstanding:</td><td></td><td></td><td></td></tr><tr><td>Basic</td><td>317,411,097</td><td>317,650,180</td><td>317,336,881</td></tr><tr><td>Diluted</td><td>318,031,580</td><td>318,454,239</td><td>318,432,687</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, Except Share Information)</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Net Income</td><td>$ 995,515</td><td>$ 949,821</td><td>$ 886,004</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>1,974</td><td>2,137</td><td>2,079</td></tr><tr><td>Changes in Unrealized (Losses)/Gains on Marketable Securities</td><td>(350)</td><td>2,294</td><td>(2,588)</td></tr><tr><td>Changes in Funded Status of Pension, SERP and PBOP Benefit Plans</td><td>(2,745)</td><td>(2,869)</td><td>7,674</td></tr><tr><td>Other Comprehensive (Loss)/Income, Net of Tax</td><td>(1,121)</td><td>1,562</td><td>7,165</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>$ 986,875</td><td>$ 943,864</td><td>$ 885,650</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="2">Common Shares</td><td rowspan="2">Capital Surplus, Paid In</td><td rowspan="2">Retained Earnings</td><td rowspan="2">Accumulated Other Comprehensive Loss</td><td rowspan="2">Treasury Stock</td><td rowspan="2">Total Common Shareholders&#x27; Equity</td></tr><tr><td>Shares</td><td>Amount</td></tr><tr><td>Balance as of January 1, 2015</td><td>316,983,337</td><td>$ 1,666,796</td><td>$ 6,235,834</td><td>$ 2,448,661</td><td>$ (74,009)</td><td>$ (300,467)</td><td>$ 9,976,815</td></tr><tr><td>Net Income</td><td></td><td></td><td></td><td>886,004</td><td></td><td></td><td>886,004</td></tr><tr><td>Dividends on Common Shares - $1.67 Per Share</td><td></td><td></td><td></td><td>(529,791)</td><td></td><td></td><td>(529,791)</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>503,443</td><td>2,517</td><td>6,951</td><td></td><td></td><td></td><td>9,468</td></tr><tr><td>Long-Term Incentive Plan Activity</td><td></td><td></td><td>(6,140)</td><td></td><td></td><td></td><td>(6,140)</td></tr><tr><td>Increase in Treasury Shares</td><td>(295,531)</td><td></td><td>22,070</td><td></td><td></td><td>(9,510)</td><td>12,560</td></tr><tr><td>Other Changes in Shareholders&#x27; Equity</td><td></td><td></td><td>3,653</td><td></td><td></td><td></td><td>3,653</td></tr><tr><td>Other Comprehensive Income</td><td></td><td></td><td></td><td></td><td>7,165</td><td></td><td>7,165</td></tr><tr><td>Balance as of December 31, 2015</td><td>317,191,249</td><td>1,669,313</td><td>6,262,368</td><td>2,797,355</td><td>(66,844)</td><td>(309,977)</td><td>10,352,215</td></tr><tr><td>Net Income</td><td></td><td></td><td></td><td>949,821</td><td></td><td></td><td>949,821</td></tr><tr><td>Dividends on Common Shares - $1.78 Per Share</td><td></td><td></td><td></td><td>(564,486)</td><td></td><td></td><td>(564,486)</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>15,787</td><td>79</td><td>(5,639)</td><td></td><td></td><td></td><td>(5,560)</td></tr><tr><td>Long-Term Incentive Plan Activity</td><td></td><td></td><td>(6,056)</td><td></td><td></td><td></td><td>(6,056)</td></tr><tr><td>Increase in Treasury Shares</td><td>(321,228)</td><td></td><td></td><td></td><td></td><td>(7,794)</td><td>(7,794)</td></tr><tr><td>Other Changes in Shareholders&#x27; Equity</td><td></td><td></td><td>(449)</td><td></td><td></td><td></td><td>(449)</td></tr><tr><td>Other Comprehensive Income</td><td></td><td></td><td></td><td></td><td>1,562</td><td></td><td>1,562</td></tr><tr><td>Balance as of December 31, 2016</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></table>

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



<table><tr><td rowspan="2">(Thousands of Dollars)</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Operating Activities:</td><td></td><td></td><td></td></tr><tr><td>Net Income</td><td>$     995,515</td><td>$     949,821</td><td>$     886,004</td></tr><tr><td>Adjustments to Reconcile Net Income to Net Cash Flows</td><td></td><td></td><td></td></tr><tr><td>Provided by Operating Activities:</td><td></td><td></td><td></td></tr><tr><td>Depreciation</td><td>773,802</td><td>715,466</td><td>665,856</td></tr><tr><td>Deferred Income Taxes</td><td>491,630</td><td>466,463</td><td>491,736</td></tr><tr><td>Pension, SERP and PBOP Expense</td><td>22,454</td><td>39,912</td><td>96,017</td></tr><tr><td>Pension and PBOP Contributions</td><td>(242,800)</td><td>(158,741)</td><td>(162,452)</td></tr><tr><td>Regulatory (Under)/Over Recoveries, Net</td><td>(47,935)</td><td>13,340</td><td>(163,287)</td></tr><tr><td>Amortization of Regulatory Assets, Net</td><td>89,986</td><td>71,696</td><td>22,339</td></tr><tr><td>Refunds/(Payments) Related to Spent Nuclear Fuel, Net</td><td>—</td><td>59,804</td><td>(297,253)</td></tr><tr><td>Other</td><td>(148,429)</td><td>(77,294)</td><td>(82,219)</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>(117,155)</td><td>(142,699)</td><td>(39,797)</td></tr><tr><td>Fuel, Materials, Supplies and Inventory</td><td>(9,223)</td><td>7,755</td><td>34,112</td></tr><tr><td>Taxes Receivable/Accrued, Net</td><td>52,284</td><td>234,543</td><td>30,282</td></tr><tr><td>Accounts Payable</td><td>56,067</td><td>(14,126)</td><td>(91,618)</td></tr><tr><td>Other Current Assets and Liabilities, Net</td><td>88,738</td><td>9,112</td><td>44,031</td></tr><tr><td>Net Cash Flows Provided by Operating Activities</td><td>2,004,934</td><td>2,175,052</td><td>1,433,751</td></tr><tr><td>Investing Activities:</td><td></td><td></td><td></td></tr><tr><td>Investments in Property, Plant and Equipment</td><td>(2,348,105)</td><td>(1,976,867)</td><td>(1,724,139)</td></tr><tr><td>Proceeds from Sales of Marketable Securities</td><td>832,903</td><td>659,338</td><td>799,165</td></tr><tr><td>Purchases of Marketable Securities</td><td>(810,507)</td><td>(681,272)</td><td>(717,114)</td></tr><tr><td>Acquisition of Aquarion</td><td>(877,652)</td><td>—</td><td>—</td></tr><tr><td>Payments to Acquire Investments</td><td>(32,634)</td><td>(188,958)</td><td>(23,353)</td></tr><tr><td>Other Investing Activities</td><td>25,521</td><td>36,951</td><td>6,291</td></tr><tr><td>Net Cash Flows Used in Investing Activities</td><td>(3,210,474)</td><td>(2,150,808)</td><td>(1,659,150)</td></tr><tr><td>Financing Activities:</td><td></td><td></td><td></td></tr><tr><td>Cash Dividends on Common Shares</td><td>(602,083)</td><td>(564,486)</td><td>(529,791)</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>72,810</td><td>(12,453)</td><td>(242,122)</td></tr><tr><td>Issuance of Long-Term Debt</td><td>2,500,000</td><td>800,000</td><td>1,225,000</td></tr><tr><td>Retirements of Long-Term Debt</td><td>(745,000)</td><td>(200,000)</td><td>(216,700)</td></tr><tr><td>Other Financing Activities</td><td>(4,754)</td><td>(33,482)</td><td>(18,225)</td></tr><tr><td>Net Cash Flows Provided by/(Used in) Financing Activities</td><td>1,213,454</td><td>(17,940)</td><td>210,643</td></tr><tr><td>Net Increase/(Decrease) in Cash and Cash Equivalents</td><td>7,914</td><td>6,304</td><td>(14,756)</td></tr><tr><td>Cash and Cash Equivalents - Beginning of Year</td><td>30,251</td><td>23,947</td><td>38,703</td></tr><tr><td>Cash and Cash Equivalents - End of Year</td><td>$     38,165</td><td>$     30,251</td><td>$     23,947</td></tr></table>

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

The 2017 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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. 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 SUBSIDIARY

# 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 4 million electric, natural gas and water customers through eight regulated utilities in Connecticut, Massachusetts and New Hampshire.

On December 4, 2017, Eversource completed the acquisition of Aquarion (formerly Macquarie Utilities Inc.) from Macquarie Infrastructure Partners for $1.675 billion, consisting of approximately $880 million in cash and $795 million of assumed Aquarion debt. Aquarion became an indirect wholly-owned subsidiary of Eversource. Aquarion is a holding company primarily engaged, through its three separate regulated water utility subsidiaries, in the water collection, treatment and distribution business. Eversource's consolidated financial information includes Aquarion and its subsidiaries' activity from December 4, 2017 through December 31, 2017. See Note 22A, "Acquisition of Aquarion and Goodwill - Acquisition of Aquarion," for further information.

On December 31, 2017, Western Massachusetts Electric Company ("WMECO") was merged into NSTAR Electric. In accordance with accounting guidance on combinations between entities under common control, the net assets, results of operations and cash flows of WMECO are reflected in the NSTAR Electric financial statements. NSTAR Electric's financial statements for all periods presented in this combined Annual Report on Form 10-K have been retrospectively recast as if the merger occurred on the first day of the earliest reporting period. All contracts and operations of WMECO are now part of NSTAR Electric. Balance sheet and income statement adjustments were made for consistent presentation between WMECO's and NSTAR Electric's financial statements, including the elimination of intercompany transactions and a merger-related transaction for common equity. Balance sheet adjustments included the elimination of intercompany accounts receivable and payable between NSTAR Electric and WMECO. Income statement adjustments included the elimination of intercompany revenues and expenses between NSTAR Electric and WMECO.

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 and Yankee Gas, the DPU for NSTAR Electric and NSTAR Gas, the NHPUC for PSNH, and the PURA, the DPU and the NHPUC for 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 included the results of PSNH's generation facilities and NSTAR Electric's solar power facilities. Eversource also has a regulated subsidiary, NPT, which was formed to construct, own and operate the Northern Pass line, a HVDC transmission line from Québec to New Hampshire under development that will interconnect with a new HVDC transmission line being developed by a transmission subsidiary of HQ.

On January 10, 2018, Eversource and PSNH completed the sale of PSNH's thermal generation assets. See Note 12, "Assets Held for 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. Eversource holds several equity ownership interests, which are accounted for under the equity method. Eversource also 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.

## 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 CYAPC and YAEC because CL&P's, NSTAR Electric's and PSNH's combined ownership interest in each of these entities is greater than 50 percent. Intercompany transactions between CL&P, NSTAR Electric and PSNH and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.

Eversource's utility subsidiaries' electric and natural gas distribution (including generation assets), transmission and water 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.

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.

As of December 31, 2017 and 2016, Eversource's carrying amount of goodwill was approximately $4.4 billion and $3.5 billion, respectively. 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, 2017 and determined that no impairment exists. See Note 22B, "Acquisition of Aquarion and Goodwill - Goodwill," for further information.

## C. Northern Pass

Northern Pass is Eversource's planned 1,090 MW HVDC transmission line that will interconnect from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. On February 1, 2018, the New Hampshire Site Evaluation Committee ("NHSEC") voted to deny Northern Pass' siting application. On February 14, 2018, pursuant to the NHSEC's decision, the Massachusetts EDCs, in coordination with the DOER and an independent evaluator, notified NPT that the EDCs will continue contract negotiations, with the option of discontinuing discussions and terminating its conditional selection by March 27, 2018.

Consistent with Eversource’s and HQ’s long-term relationship to bring clean energy into New England, Eversource and HQ continue to support Northern Pass and the many benefits this project will bring to our customers and region. Eversource intends to seek reconsideration of the NHSEC’s decision and to review all options for moving this critical clean energy project forward.

As of December 31, 2017, Eversource has approximately $277 million in capitalized costs associated with Northern Pass. The Company continues to believe that the Northern Pass project is probable of being placed in service. If in the future, events and changes in circumstances indicate that the Northern Pass project's capitalized costs may not be fully recoverable, the Company will then evaluate those costs for impairment. Should the Company conclude that these capitalized costs are impaired, this would have a significant negative impact on Eversource's financial position, results of operations, and cash flows.

## D. Accounting Standards

Accounting Standards Issued but Not Yet Effective: In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2014-09, Revenue from Contracts with Customers, which amends existing revenue recognition guidance and is required to be applied either fully retrospectively (to each reporting period presented) or under a modified retrospective method (cumulatively at the date of initial application). The FASB deferred implementation of ASU 2014-09 in ASU 2015-14, Revenue from Contracts with Customers (Topic: 606): Deferral of the Effective Date. The new accounting guidance is effective for interim and annual periods beginning in 2018 with early adoption permitted. The Company implemented the standard in the first quarter of 2018 using the modified retrospective method of adoption. Under this method of adoption, prior year reported results are not restated.

Under the new standard, an entity must identify the performance obligations in a contract, determine the transaction price and allocate the price to specific performance obligations to recognize the revenue when the obligation is completed. The amendments in this ASU also require disclosure of sufficient information to allow users to understand the nature, amount, timing and uncertainty of revenue and cash flow arising from contracts.

The Company has reviewed and performed accounting analyses of its revenue streams under contracts with customers. These accounting analyses included reviewing representative contracts and tariffs for each material revenue stream and evaluating them under the new guidance. The majority of the Company’s sales are derived from tariffs to provide electric and natural gas to customers. For such tariffs, the Company expects that the revenue from contracts with customers under ASU 2014-09 will be equivalent to revenue from electricity and natural gas supplied and billed in that period (including estimated unbilled revenues), which is consistent with current practice.

Based on our assessments, the Company has identified one item that will be accounted for differently under the new revenue guidance as compared to current guidance. As a result of applying guidance on the unit of account under the new standard, purchases and sales of power from and to ISO-New England will be accounted for net by the hour, rather than net by the month, with no impact on net income.

After taking into consideration this identified change, the Company has concluded that the new guidance will not have a material impact on the amounts or timing of revenue recognition. Implementation of the ASU will not have a material effect on the results of operations, financial



position or cash flows of Eversource, CL&P, NSTAR Electric or PSNH. Significant additional disclosures of the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers will be presented beginning in the first quarter of 2018.

In January 2016, the FASB issued ASU 2016-01, Financial Instruments - Overall: Recognition and Measurement of Financial Assets and Liabilities, which is required to be implemented in the first quarter of 2018. The ASU will remove the available-for-sale designation for equity securities, whereby changes in fair value are recorded in accumulated other comprehensive income within shareholders' equity, and will require changes in fair value of all equity securities to be recorded in earnings beginning on January 1, 2018, with the unrealized gain or loss on available-for-sale equity securities as of that date reclassified to retained earnings as a cumulative effect of adoption. The fair value of available-for-sale equity securities subject to this guidance as of December 31, 2017 was approximately $51 million with an unrealized loss of $0.1 million. The unrealized loss recorded in AOCI will be recorded as an adjustment to the opening balance of retained earnings as of January 1, 2018. The remaining available-for-sale equity securities included in marketable securities on the balance sheet are held in nuclear decommissioning trusts and are subject to regulatory accounting treatment and will not be impacted by this guidance. Implementation of the ASU for other financial instruments is not expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric or PSNH.

In February 2016, the FASB issued ASU 2016-02, Leases, which changes existing lease accounting guidance and is required to be applied in the first quarter of 2019, with earlier application permitted. The ASU lease criteria are required to be applied to leases and lease renewals entered into effective January 1, 2019, and leases entered into before that date are required to be recognized and measured using a modified retrospective approach. The Company is reviewing the requirements of ASU 2016-02, including balance sheet recognition of leases previously deemed to be operating leases, and expects to implement the ASU in the first quarter of 2019.

In March 2017, the FASB issued ASU 2017-07, Compensation – Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost, required to be implemented in the first quarter of 2018. The ASU requires separate presentation of service cost from other components of net pension and PBOP costs, with the other components presented as non-operating income and not subject to capitalization. The ASU is required to be applied retrospectively for the separate presentation in the income statement of service costs and other components and prospectively in the balance sheet for the capitalization of only the service cost component. The implementation of the ASU will not have an impact on the net income of Eversource, CL&P, NSTAR Electric or PSNH.

## E. Cash and Cash Equivalents

Cash and cash equivalents include cash on hand and short-term cash investments that are highly liquid in nature and have original maturities of three months or less. At the end of each reporting period, any overdraft amounts are reclassified from Cash and Cash Equivalents 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 both uncollectible accounts and for uncollectible hardship accounts (the uncollectible hardship balance is included in the total provision) is included in Receivables, Net on the balance sheets, and was as follows:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="3">Total Provision for Uncollectible Accounts</td><td colspan="3">Uncollectible Hardship</td></tr><tr><td colspan="3">As of December 31,</td><td colspan="3">As of December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2017</td><td>2016</td><td>2017</td><td>2016</td></tr><tr><td>Eversource</td><td>$     195.7</td><td>$     200.6</td><td>$     122.5</td><td>$     119.9</td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>78.9</td><td>86.4</td><td>65.5</td><td>67.7</td><td></td><td></td></tr><tr><td>NSTAR Electric</td><td>69.7</td><td>70.3</td><td>40.3</td><td>36.1</td><td></td><td></td></tr><tr><td>PSNH</td><td>10.5</td><td>9.9</td><td>—</td><td>—</td><td></td><td></td></tr></table>

## G. Fuel, Materials, Supplies and Inventory

Fuel, Materials, Supplies and Inventory include natural gas, coal, biomass and oil inventories, materials and supplies purchased primarily for construction or operation and maintenance purposes, RECs and emission allowances. 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.

PSNH is subject to federal and state laws and regulations that regulate emissions of air pollutants, including  \( SO_{2} \) ,  \( CO_{2} \) , and  \( NO_{x} \)  related to its regulated generation units, and used  \( SO_{2} \) ,  \( CO_{2} \) , and  \( NO_{x} \)  emissions allowances.  \( SO_{2} \) ,  \( CO_{2} \) , and  \( N_{O_{x}} \)  emissions allowances were charged to expense based on their average cost as they were utilized against emissions volumes at PSNH's generating units.

On October 11, 2017, PSNH entered into two Purchase and Sale Agreements ("Agreements") to sell its thermal and hydroelectric generation assets. The NHPUC approved the Agreements in late November 2017 and on January 10, 2018, PSNH completed the sale of its thermal



generation assets. As of December 31, 2017, PSNH has classified its generation assets, which included coal, biomass and oil inventories and emission allowances, as held for sale. As of December 31, 2016, these inventories were recorded within Fuel, Materials, Supplies and Inventory on the balance sheet. See Note 12, "Assets Held for Sale," for further information.

The carrying amounts of fuel, materials and supplies, RECs, and emission allowances were as follows:

As of December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">2017</td><td colspan="5">2016</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>Current:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Fuel</td><td>$ 29.7</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ 135.7</td><td>$ —</td><td>$ —</td><td>$ —</td><td>99.9</td></tr><tr><td>Materials and Supplies</td><td>117.1</td><td>44.4</td><td>45.1</td><td>18.5</td><td>142.7</td><td>48.2</td><td>39.7</td><td>47.3</td><td></td></tr><tr><td>RECs</td><td>76.3</td><td>4.0</td><td>50.4</td><td>21.8</td><td>47.9</td><td>3.9</td><td>31.2</td><td>12.8</td><td></td></tr><tr><td>Emission Allowances</td><td>—</td><td>—</td><td>—</td><td>—</td><td>2.4</td><td>—</td><td>—</td><td>2.4</td><td></td></tr><tr><td>Long-Term:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Emission Allowances</td><td>—</td><td>—</td><td>—</td><td>—</td><td>17.5</td><td>—</td><td>—</td><td>17.5</td><td></td></tr></table>

## H. Deposits

As of December 31, 2017, Eversource, CL&P, NSTAR Electric and PSNH had $24.5 million, $3.1 million, $12.8 million and $0.5 million, respectively, of cash collateral posted not subject to master netting agreements, with ISO-NE related to energy transactions, which was included in Prepayments and Other Current Assets on the balance sheets. As of December 31, 2016, these amounts were $21.7 million, $1.4 million, $11.8 million and $0.5 million for Eversource, CL&P, NSTAR Electric and PSNH, respectively.

## 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 and AROs, and the estimated fair value of preferred stock and long-term debt.

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.

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, "Asset Retirement Obligations," Note 9A, "Employee Benefits – Pension Benefits and Postretirement Benefits Other Than Pensions," and Note 14, "Fair Value of Financial Instruments" 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. For the regulated companies, 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.

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 and 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.

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. Investments

Investments are included in Other Long-Term Assets on the balance sheets and earnings impacts from equity investments are included in Other Income, Net on the statements of income.

Strategic, Infrastructure and Other Investments: As of December 31, 2017 and 2016, Eversource had investments totaling $277.6 million and $236.9 million, respectively. As of December 31, 2017 and 2016, Eversource's investments included a 15 percent ownership interest in a FERC-regulated natural gas transmission business of $159.6 million and $154.6 million, respectively, a 40 percent ownership interest in Access Northeast of $31.3 million and $30.9 million, respectively, a 37.2 percent (14.5 percent of which related to NSTAR Electric) ownership interest in two companies that transmit hydro-electricity imported from the Hydro-Quebec system in Canada of $17.7 million and $7.7 million, respectively, and other investments totaling $69.0 million and $43.7 million, respectively. NSTAR Electric's investments totaled $6.9 million and $3.0 million, respectively, as of December 31, 2017 and 2016.

Regional Decommissioned Nuclear Companies: CL&P, NSTAR Electric and PSNH own common stock in three regional nuclear generation companies (CYPAC, YAEC and MYAPC, collectively referred to as the "Yankee Companies"), each of which owned a single nuclear generating facility that has been decommissioned. For CL&P, NSTAR Electric and PSNH, the respective investments in CYPAC, YAEC and MYAPC are accounted for under the equity method and are included in Other Long-Term Assets on their respective balance sheets. Eversource consolidates CYPAC and YAEC because CL&P's, NSTAR Electric's and PSNH's combined ownership interest in each of these entities is greater than 50 percent. For further information on the Yankee Companies, see Note 11C, "Commitments and Contingencies – Spent Nuclear Fuel Obligations – Yankee Companies," to the financial statements.

Equity in Earnings and Dividends from Equity Investments: For the years ended December 31, 2017, 2016 and 2015, Eversource had equity in earnings of $27.4 million, $0.2 million, and $0.9 million, respectively. Eversource received dividends from its equity method investees of $20.0 million and $0.1 million, respectively, for the years ended December 31, 2017 and 2016.

## L. Revenues

Retail Revenues: Retail revenues are based on rates approved by 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 also used to recover certain costs on a fully-reconciling basis. These tracking mechanisms require rates to be changed periodically to ensure recovery of actual costs incurred.

Certain Eversource electric, natural gas and water companies, including CL&P and NSTAR Electric (for a portion of its customers), have a regulatory commission approved revenue decoupling mechanism ("decoupled companies"). Distribution revenues are decoupled from customer sales volumes, where applicable, which breaks the relationship between sales volumes and revenues recognized. The decoupled companies reconcile their annual base distribution rate recovery to pre-established levels of baseline distribution delivery service revenues. Any difference between the allowed level of distribution revenue and the actual amount realized is adjusted through rates in a subsequent period.

A significant portion of the electric and natural gas companies' retail revenues relate to the recovery of costs incurred for the sale of electricity and natural gas purchased on behalf of customers. These energy supply costs are recovered from customers in rates through cost tracking mechanisms. Energy purchases are recorded in Purchased Power, Fuel and Transmission, and the sales of energy associated with these purchases are recorded in Operating Revenues on the statements of income.

Unbilled Revenues: Because customers are billed throughout the month based on pre-determined cycles rather than on a calendar month basis, an estimate of electricity, natural gas or water delivered to customers for which the customers have not yet been billed is calculated as of the balance sheet date. Unbilled revenues are included in Operating Revenues on the statements of income and in Current Assets on the balance sheets. 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 revenues can vary significantly from period to period as a result of seasonality, weather, customer usage patterns, customer rates in effect for customer classes, and the timing of customer billing. The estimate of unbilled revenues can significantly impact the amount of revenues recorded at the companies that do not have a revenue decoupling mechanism. Companies that do have a decoupling mechanism record a regulatory deferral to reflect the actual allowed amount of revenue associated with their respective decoupled distribution rate design.



Transmission Revenues - Wholesale Rates: 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 and NSTAR Electric each have two sets of local rates that 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. 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. See Note 11E, "Commitments and Contingencies – FERC ROE Complaints," for complaints filed at the FERC relating to Eversource's ROE.

Transmission Revenues - Retail Rates: A significant portion of the Eversource electric transmission segment revenue comes from ISO-NE charges to the distribution businesses of CL&P, NSTAR Electric, and PSNH, each of which recovers these costs through rates charged to their retail customers. CL&P, NSTAR Electric and PSNH each have a retail transmission cost tracking mechanism as part of their rates, which allows the electric distribution companies to charge their retail customers for transmission costs on a timely basis.

## M. 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="3">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2015</td></tr><tr><td>Eversource - Natural Gas and Fuel</td><td>$ 432.5</td><td>$ 372.2</td><td>$ 516.7</td></tr><tr><td>PSNH - Fuel</td><td>43.4</td><td>45.0</td><td>85.4</td></tr></table>

## N. 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>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Borrowed Funds</td><td>$ 12.5</td><td>$ 10.8</td><td>$ 7.2</td><td></td></tr><tr><td>Equity Funds</td><td>34.4</td><td>26.2</td><td>18.8</td><td></td></tr><tr><td>Total AFUDC</td><td>$ 46.9</td><td>$ 37.0</td><td>$ 26.0</td><td></td></tr><tr><td>Average AFUDC Rate</td><td>5.1%</td><td>4.4%</td><td>3.9%</td><td></td></tr></table>

<table><tr><td rowspan="2">(Millions of Dollars, except percentages)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Borrowed Funds</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>NSTAR Electric</td><td>NSTAR Electric</td></tr><tr><td>Borrowed Funds</td><td>$ 5.1</td><td>$ 4.8</td><td>$ 0.7</td><td>$ 3.3</td></tr><tr><td>Equity Funds</td><td>12.1</td><td>10.2</td><td>6.3</td><td>10.2</td></tr><tr><td>Total AFUDC</td><td>$ 17.2</td><td>$ 15.0</td><td>$ 9.6</td><td>$ 15.5</td></tr><tr><td>Average AFUDC Rate</td><td>6.2%</td><td>5.0%</td><td>4.7%</td><td>3.2%</td></tr></table>

## O. Other Income, Net

Items included within Other Income, Net on the statements of income primarily consist of investment income/(loss) related to debt and equity securities held in trust, market value changes related to deferred compensation plans, interest income, AFUDC related to equity funds, and income/(loss) related to equity method investees. For further information on gains/(losses) related to debt and equity securities, see Note 5, "Marketable Securities," to the financial statements. For further information on AFUDC related to equity funds, see Note 1N, "Summary of Significant Accounting Policies – Allowance for Funds Used During Construction," to the financial statements. For further information on equity in earnings, see Note 1K, "Summary of Significant Accounting Policies – Investments," to the financial statements.

## P. 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 shown 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>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Eversource</td><td>$ 157.4</td><td>$ 162.7</td><td>$ 147.2</td><td></td></tr><tr><td>CL&amp;P</td><td>137.5</td><td>145.2</td><td>128.5</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.

Separately from the amounts above are $25.4 million of expense recorded as Taxes Other than Income Taxes in 2017 related to the future remittance of energy efficiency funds collected from customers in Operating Revenues to the State of Connecticut. These amounts are shown separately with collections in Operating Revenues and expenses in Taxes Other than Income Taxes on the Eversource and CL&P statements of income.

## Q. Supplemental Cash Flow Information

<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>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Cash Paid/(Received) During the Year for:</td><td></td><td></td><td></td><td></td></tr><tr><td>Interest, Net of Amounts Capitalized</td><td>$ 419.1</td><td>$ 398.1</td><td>$ 365.9</td><td></td></tr><tr><td>Income Taxes</td><td>30.8</td><td>(135.5)</td><td>10.3</td><td></td></tr><tr><td>Non-Cash Investing Activities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Plant Additions Included in Accounts Payable (As of)</td><td>379.5</td><td>301.5</td><td>216.6</td><td></td></tr></table>

As of and For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="3">2017</td><td colspan="3">2016</td><td colspan="3">2015</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></tr><tr><td>(Millions of Dollars)</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Cash Paid/(Received) 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>$ 124.6</td><td>$ 45.9</td><td>$ 143.3</td><td>$ 112.9</td><td>$ 46.5</td><td>$ 144.4</td><td>$ 102.4</td><td>$ 42.3</td></tr><tr><td>Income Taxes</td><td>68.8</td><td>95.5</td><td>26.1</td><td>(73.9)</td><td>66.0</td><td>(36.0)</td><td>55.2</td><td>(5.1)</td><td>14.4</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)</td><td>132.5</td><td>116.5</td><td>44.4</td><td>116.2</td><td>87.0</td><td>37.9</td><td>76.0</td><td>50.5</td><td>46.5</td></tr></table>

In 2016, as a result of damages awarded to the Yankee Companies for spent nuclear fuel lawsuits against the DOE described in Note 11C, "Commitments and Contingencies – Spent Nuclear Fuel Obligations – Yankee Companies," CYAPC and YAEC received total proceeds of $52.2 million, which were classified as operating activities on the Eversource consolidated statements of cash flows. CYAPC returned $6.8 million of these proceeds to its non-affiliated member companies. In addition, CL&P, NSTAR Electric and PSNH received a total distribution of $14.4 million from MYAPC as a result of DOE Phase III proceeds and a distribution from its spent nuclear fuel trust.

The 2015 cash paid for interest excludes interest payments made by CL&P and NSTAR Electric in connection with the full satisfaction of their respective obligations to the DOE for the disposal of spent nuclear fuel and high-level radioactive waste for all periods prior to 1983 from their previous ownership interest in the Millstone nuclear power stations. CL&P and NSTAR Electric divested their ownership interest in Millstone in 2001. In late 2015, CL&P and NSTAR Electric made payments of $244.6 million and $57.4 million, respectively, to satisfy their pre-1983 spent nuclear fuel obligations to the DOE in full, which included accumulated interest of $178 million and $41.8 million, respectively.

## R. Related Parties

Eversource Service, Eversource's service company, provides centralized accounting, administrative, engineering, financial, information technology, legal, operational, planning, purchasing, 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, 2017 and 2016, CL&P, NSTAR Electric and PSNH had long-term receivables from Eversource Service in the amounts of $25.0 million, $3.8 million and $5.5 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, 2017 and 2016 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.



## 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, including a return on investment.

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">Eversource (Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2017</td><td>2016</td></tr><tr><td>Benefit Costs</td><td>2,068.8</td><td>1,817.8</td></tr><tr><td>Deferred Costs from Generation Asset Sale</td><td>516.1</td><td>—</td></tr><tr><td>Derivative Liabilities</td><td>367.2</td><td>423.3</td></tr><tr><td>Income Taxes, Net</td><td>768.9</td><td>644.5</td></tr><tr><td>Storm Restoration Costs</td><td>404.8</td><td>385.3</td></tr><tr><td>Goodwill-related</td><td>365.2</td><td>464.4</td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>509.9</td><td>576.6</td></tr><tr><td>Asset Retirement Obligations</td><td>101.0</td><td>99.3</td></tr><tr><td>Other Regulatory Assets</td><td>137.4</td><td>115.1</td></tr><tr><td>Total Regulatory Assets</td><td>5,239.3</td><td>4,526.3</td></tr><tr><td>Less: Current Portion</td><td>741.9</td><td>887.6</td></tr><tr><td>Total Long-Term Regulatory Assets</td><td>4,497.4</td><td>3,638.7</td></tr></table>

As of December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">2017</td><td colspan="4">2016</td></tr><tr><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td><td colspan="2">PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td></tr><tr><td>Benefit Costs</td><td>$ 469.2</td><td>$ 560.7</td><td>$ 212.3</td><td>$ 212.3</td><td>$ 429.3</td><td>$ 525.3</td><td>$ 184.2</td><td></td></tr><tr><td>Deferred Costs from Generation Asset Sale</td><td>—</td><td>—</td><td>516.1</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Derivative Liabilities</td><td>362.3</td><td>—</td><td>—</td><td>—</td><td>420.5</td><td>2.8</td><td>—</td><td>—</td></tr><tr><td>Income Taxes, Net</td><td>453.8</td><td>113.2</td><td>21.7</td><td>437.0</td><td>120.5</td><td>24.2</td><td></td><td></td></tr><tr><td>Storm Restoration Costs</td><td>216.7</td><td>146.6</td><td>41.5</td><td>239.8</td><td>128.4</td><td>17.1</td><td></td><td></td></tr><tr><td>Goodwill-related</td><td>—</td><td>313.6</td><td>—</td><td>—</td><td>398.7</td><td>—</td><td></td><td></td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>85.3</td><td>273.0</td><td>116.4</td><td>123.9</td><td>304.0</td><td>104.5</td><td></td><td></td></tr><tr><td>Asset Retirement Obligations</td><td>30.3</td><td>39.0</td><td>17.0</td><td>33.2</td><td>36.1</td><td>16.2</td><td></td><td></td></tr><tr><td>Other Regulatory Assets</td><td>27.6</td><td>78.4</td><td>15.8</td><td>43.4</td><td>22.7</td><td>16.5</td><td></td><td></td></tr><tr><td>Total Regulatory Assets</td><td>1,645.2</td><td>1,524.5</td><td>940.8</td><td>1,727.1</td><td>1,538.5</td><td>362.7</td><td></td><td></td></tr><tr><td>Less: Current Portion</td><td>200.3</td><td>333.9</td><td>130.1</td><td>335.5</td><td>353.5</td><td>117.2</td><td></td><td></td></tr><tr><td>Total Long-Term Regulatory Assets</td><td>$ 1,444.9</td><td>$ 1,190.6</td><td>$ 810.7</td><td>$ 1,391.6</td><td>$ 1,185.0</td><td>$ 245.5</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.

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.

Deferred Costs from Generation Asset Sale: Represents PSNH's $516.1 million of deferred costs associated with the sale of PSNH's generation assets that are expected to be recovered. These deferred costs were the difference between the carrying value and the fair value less costs to sell of the thermal generation assets that were classified as held for sale as of December 31, 2017. Full recovery of PSNH's generation assets (including these deferred costs and the results of the sale of the hydro generation assets) are expected to occur through a combination of cash flows during the



remaining operating period, sales proceeds, and recovery of stranded costs via the issuance of bonds that will be secured by a non-bypassable charge or through recoveries in future rates billed to PSNH's customers. For further information, see Note 12, "Assets Held for Sale."

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.

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 10, "Income Taxes," to the financial statements.

Storm Restoration Costs: The storm restoration cost deferrals relate to costs incurred for major 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 as a major storm with the criteria specific to each state jurisdiction and utility company. Once a storm qualifies as a major storm, all qualifying expenses incurred during storm restoration efforts are deferred and recovered from customers. In addition to storm restoration costs, CL&P and PSNH are each allowed to recover pre-staging storm costs. Management believes the storm restoration costs were prudent 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 process. Each electric utility has sought, or is seeking, recovery of its deferred storm restoration costs through its applicable regulatory recovery process. 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.

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, 2017, there were 22 years of amortization remaining.

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. Energy procurement costs at PSNH include the costs related to its generation facilities and at NSTAR Electric include the costs related to its solar power facilities.

CL&P, NSTAR Electric (for their western Massachusetts customer rates) 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 recognized. In 2017 and 2016, NSTAR Electric operated under two different rate structures based on its service territory geography. For customers that were served in eastern Massachusetts, including metropolitan Boston, Cape Cod and Martha's Vineyard, NSTAR Electric operated using traditional rates. For customers that were served in western Massachusetts, including the metropolitan Springfield region, NSTAR Electric operated using decoupled rates. Effective February 1, 2018, all of NSTAR Electric's distribution revenues were decoupled as a result of the DPU-approved rate decision. CL&P and NSTAR Electric reconciled their annual base distribution rate recovery amounts to their pre-established levels of baseline distribution delivery service revenues of $1.059 billion and $132.4 million, respectively, through December 31, 2017. Effective February 1, 2018, NSTAR Electric, operating entirely under decoupled rates, will reconcile its annual base distribution rate recovery to its new baseline of $974.8 million. 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.

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 remaining nuclear fuel storage costs of the CYAPC, YAEC and MYAPC nuclear 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 $105.8 million (including $18.2 million for CL&P, $42.7 million for NSTAR Electric and $27.2 million for PSNH) and $86.3 million (including $5.9 million for CL&P, $55.1 million for NSTAR Electric and $8.2 million for PSNH) of additional regulatory costs as of December 31, 2017 and 2016, 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 $1.0 million and $1.2 million for CL&P as of December 31, 2017 and 2016, respectively. These carrying costs will be recovered from customers in future rates. As of December 31, 2017 and 2016, this equity return, which is not recorded on the balance sheets, totaled $42.0 million and $44.9 million, respectively, for PSNH. These amounts include $25 million of equity return on the Clean Air Project costs that PSNH has agreed not to bill customers as part of a generation divestiture settlement agreement.

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

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="3">As of December 31,</td></tr><tr><td>2017</td><td>2016</td><td></td></tr><tr><td>Cost of Removal</td><td>$ 502.1</td><td>$ 459.7</td><td></td></tr><tr><td>Benefit Costs</td><td>132.3</td><td>136.2</td><td></td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>136.7</td><td>145.3</td><td></td></tr><tr><td>AFUDC - Transmission</td><td>67.1</td><td>65.8</td><td></td></tr><tr><td>Other Regulatory Liabilities</td><td>45.2</td><td>42.1</td><td></td></tr><tr><td>Total Regulatory Liabilities  \( {}^{(1)} \)</td><td>883.4</td><td>849.1</td><td></td></tr><tr><td>Less: Current Portion</td><td>128.1</td><td>146.8</td><td></td></tr><tr><td>Total Long-Term Regulatory Liabilities  \( {}^{(1)} \)</td><td>$ 755.3</td><td>$ 702.3</td><td></td></tr></table>

As of December 31,

<table><tr><td rowspan="2"></td><td colspan="6">As of December 31,</td></tr><tr><td colspan="3">2017</td><td colspan="3">2016</td></tr><tr><td>(Millions of Dollars)</td><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>Cost of Removal</td><td>$ 23.2</td><td>$ 293.8</td><td>$ 37.9</td><td>$ 38.8</td><td>$ 280.2</td><td>$ 44.1</td></tr><tr><td>Benefit Costs</td><td>—</td><td>112.6</td><td>—</td><td>—</td><td>113.1</td><td>—</td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>34.6</td><td>77.8</td><td>5.0</td><td>37.2</td><td>78.4</td><td>10.7</td></tr><tr><td>AFUDC - Transmission</td><td>48.8</td><td>18.3</td><td>—</td><td>50.2</td><td>15.6</td><td>—</td></tr><tr><td>Other Regulatory Liabilities</td><td>12.9</td><td>3.7</td><td>2.7</td><td>21.0</td><td>0.3</td><td>2.7</td></tr><tr><td>Total Regulatory Liabilities  \( {}^{(1)} \)</td><td>119.5</td><td>506.2</td><td>45.6</td><td>147.2</td><td>487.6</td><td>57.5</td></tr><tr><td>Less: Current Portion</td><td>39.0</td><td>79.6</td><td>6.3</td><td>47.1</td><td>78.5</td><td>12.7</td></tr><tr><td>Total Long-Term Regulatory Liabilities  \( {}^{(1)} \)</td><td>$ 80.5</td><td>$ 426.6</td><td>$ 39.3</td><td>$ 100.1</td><td>$ 409.1</td><td>$ 44.8</td></tr></table>

(1) The amounts above do not include the impacts associated with the "Tax Cuts and Jobs Act" (the "Act"), which became law on December 22, 2017. Pursuant to the enacted law, Eversource remeasured its existing deferred federal income tax balances as of December 31, 2017 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 (ADIT) liabilities that we expect to benefit our customers in future periods, which were estimated to be approximately $2.9 billion (approximately $1.0 billion at CL&P, $1.1 billion at NSTAR Electric and $0.4 billion at PSNH) as of December 31, 2017 and recognized as regulatory liabilities on the balance sheet. We estimate that about 85 percent of the provisional regulated excess ADIT liabilities relate to property, plant, and equipment with remaining useful lives estimated to be in excess of 20 years. These amounts are subject to IRS normalization rules and would be returned to customers using the same timing as the remaining useful lives of the underlying assets that gave rise to the ADIT liabilities. The Eversource regulated companies are currently working with the state regulatory commissions, who have opened investigations to examine the impact of the Act on customer rates. For further information, see Note 10, "Income Taxes," to the financial statements.

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.

FERC ROE Complaints: As of December 31, 2017, Eversource has a reserve established for the first and second ROE complaints in the pending FERC ROE complaint proceedings, which was recorded as a regulatory liability. The cumulative pre-tax reserve (excluding interest) as of December 31, 2017, which includes the impact of refunds given to customers, 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 11E, "Commitments and Contingencies – FERC ROE Complaints," for further information on developments in the pending ROE complaint proceedings.



NSTAR Electric Distribution Rate Case Decision: On November 30, 2017, the DPU issued its decision in the NSTAR Electric distribution rate case, which approved an annual distribution rate increase of $37 million, with rates effective February 1, 2018. On January 3, 2018, NSTAR Electric filed a motion to reflect a revenue requirement reduction of $56 million (due to the decrease in the federal corporate income tax rate, as part of the "Tax Cuts and Jobs Act"), resulting in an annual net decrease in rates of $19 million.

In addition to its decision regarding rates, the DPU approved an authorized regulatory ROE of 10 percent, the establishment of a revenue decoupling rate mechanism for the portion of the NSTAR Electric business that did not previously have a decoupling mechanism, and the implementation of an inflation-based adjustment mechanism with a five-year stay-out until January 1, 2023.

Among other items, the DPU approved the recovery of previously expensed merger-related costs (which were incurred by Eversource parent in prior years) over a 10-year period and the recovery of previously deferred storm costs with carrying charges at the prime rate, but disallowed certain property taxes. The rate case decision resulted in the recognition of an aggregate $44.1 million pre-tax benefit recorded in 2017 ($14.1 million at NSTAR Electric).

CL&P Rate Case Settlement: On January 11, 2018, CL&P filed a distribution rate case settlement agreement for approval by PURA, which included, among other things, rate increases of $97.1 million, $32.7 million and $24.7 million, effective May 1, 2018, 2019, and 2020, respectively, an authorized regulatory ROE of 9.25 percent, 53 percent common equity in CL&P's capital structure, and a new capital tracker through 2020 for capital additions, system resiliency, and grid modernization. The rate increases associated with the settlement agreement will be reduced by the impact of the decrease in the federal corporate income tax rate, as part of the "Tax Cuts and Jobs Act," while amounts related to ADIT will be addressed in a separate manner. CL&P expects to receive final approval from PURA in the second quarter of 2018. No actions arose from this settlement that had an impact on previously deferred costs.

## 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, including planned major maintenance activities, 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">Eversource (Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2017</td><td>2016</td></tr><tr><td>Distribution - Electric</td><td>$ 14,410.5</td><td>$ 13,716.9</td></tr><tr><td>Distribution - Natural Gas</td><td>3,244.2</td><td>3,010.4</td></tr><tr><td>Transmission - Electric</td><td>9,270.9</td><td>8,517.4</td></tr><tr><td>Water (1)</td><td>1,558.4</td><td>—</td></tr><tr><td>Generation and Solar (2)</td><td>36.2</td><td>1,224.2</td></tr><tr><td>Utility</td><td>28,520.2</td><td>26,468.9</td></tr><tr><td>Other (3)</td><td>693.7</td><td>591.6</td></tr><tr><td>Property, Plant and Equipment, Gross</td><td>29,213.9</td><td>27,060.5</td></tr><tr><td>Less: Accumulated Depreciation</td><td></td><td></td></tr><tr><td>Utility</td><td>(6,846.9)</td><td>(6,480.4)</td></tr><tr><td>Other</td><td>(286.9)</td><td>(242.0)</td></tr><tr><td>Total Accumulated Depreciation</td><td>(7,133.8)</td><td>(6,722.4)</td></tr><tr><td>Property, Plant and Equipment, Net</td><td>22,080.1</td><td>20,338.1</td></tr><tr><td>Construction Work in Progress</td><td>1,537.4</td><td>1,012.4</td></tr><tr><td>Total Property, Plant and Equipment, Net</td><td>$ 23,617.5</td><td>$ 21,350.5</td></tr></table>

As of December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">2017</td><td colspan="3">2016</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</td><td>$ 5,888.3</td><td>$ 6,479.0</td><td>$ 2,083.4</td><td>$ 5,562.9</td><td>$ 6,244.2</td><td>$ 1,949.8</td></tr><tr><td>Transmission</td><td>4,239.9</td><td>3,821.2</td><td>1,161.3</td><td>3,912.9</td><td>3,496.9</td><td>1,059.3</td></tr><tr><td>Generation and Solar (2)</td><td>—</td><td>36.2</td><td>—</td><td>—</td><td>36.0</td><td>1,188.2</td></tr><tr><td>Property, Plant and Equipment, Gross</td><td>10,128.2</td><td>10,336.4</td><td>3,244.7</td><td>9,475.8</td><td>9,777.1</td><td>4,197.3</td></tr><tr><td>Less: Accumulated Depreciation</td><td>(2,239.0)</td><td>(2,550.2)</td><td>(751.8)</td><td>(2,082.4)</td><td>(2,364.2)</td><td>(1,254.7)</td></tr><tr><td>Property, Plant and Equipment, Net</td><td>7,889.2</td><td>7,786.2</td><td>2,492.9</td><td>7,393.4</td><td>7,412.9</td><td>2,942.6</td></tr><tr><td>Construction Work in Progress</td><td>381.8</td><td>460.3</td><td>149.4</td><td>239.0</td><td>317.2</td><td>96.7</td></tr><tr><td>Total Property, Plant and Equipment, Net</td><td>$ 8,271.0</td><td>$ 8,246.5</td><td>$ 2,642.3</td><td>$ 7,632.4</td><td>$ 7,730.1</td><td>$ 3,039.3</td></tr></table>

(1) On December 4, 2017, Eversource completed the acquisition of Aquarion. See Note 22A, "Acquisition of Aquarion and Goodwill - Acquisition of Aquarion," for further information.



(2) On October 11, 2017, PSNH entered into two Purchase and Sale Agreements ("Agreements") to sell its thermal and hydroelectric generation assets. As of December 31, 2017, PSNH has classified its generation assets as held for sale. As of December 31, 2016, these plant balances were recorded within Property, Plant and Equipment, Net on the balance sheet. See Note 12, "Assets Held for Sale," for further information.

(3) These assets are primarily comprised of building improvements, computer software, hardware and equipment at Eversource Service.

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>2017</td><td>2016</td><td>2015</td></tr><tr><td>Eversource</td><td>3.0%</td><td>3.0%</td><td>2.9%</td></tr><tr><td>CL&amp;P</td><td>2.8%</td><td>2.7%</td><td>2.7%</td></tr><tr><td>NSTAR Electric</td><td>2.9%</td><td>2.9%</td><td>2.9%</td></tr><tr><td>PSNH</td><td>3.1%</td><td>3.1%</td><td>3.2%</td></tr></table>

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

<table><tr><td rowspan="2">(Years)</td><td colspan="4">As of December 31, 2017</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Distribution</td><td>34.6</td><td>35.8</td><td>31.7</td><td>31.3</td></tr><tr><td>Transmission</td><td>40.9</td><td>37.2</td><td>44.7</td><td>43.5</td></tr><tr><td>Water</td><td>32.0</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Solar</td><td>25.0</td><td>—</td><td>25.0</td><td>—</td></tr><tr><td>Other</td><td>12.7</td><td>—</td><td>—</td><td>—</td></tr></table>



## 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 or Operating Revenues 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:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="7">As of December 31,</td></tr><tr><td colspan="3">2017</td><td colspan="3">2016</td><td rowspan="2">Recorded as a Derivative</td></tr><tr><td>Commodity Supply and Price Risk Management</td><td>Netting (1)</td><td>Recorded as a Derivative</td><td>Commodity Supply and Price Risk Management</td><td>Netting (1)</td><td>Record 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>Level 2:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ —</td><td>6.0</td><td>$ —</td><td>$ 6.0</td></tr><tr><td>Level 3:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>9.5</td><td>(7.1)</td><td>2.4</td><td>13.9</td><td>(9.4)</td><td>4.5</td><td></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>Level 2:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource</td><td>$ —</td><td>$ —</td><td>$ —</td><td>$ —</td><td>0.3</td><td>$ (0.1)</td><td>$ 0.2</td></tr><tr><td>Level 3:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>71.9</td><td>(5.3)</td><td>66.6</td><td>77.3</td><td>(11.7)</td><td>65.6</td><td></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>Level 2:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource</td><td>$ (4.5)</td><td>$ —</td><td>$ (4.5)</td><td>$ —</td><td>$ —</td><td>$ —</td><td></td></tr><tr><td>Level 3:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource</td><td>(54.4)</td><td>—</td><td>(54.4)</td><td>(79.7)</td><td>—</td><td>(79.7)</td><td></td></tr><tr><td>CL&amp;P</td><td>(54.4)</td><td>—</td><td>(54.4)</td><td>(77.8)</td><td>—</td><td>(77.8)</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>Level 2:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource</td><td>$ (0.4)</td><td>$ —</td><td>$ (0.4)</td><td>$ —</td><td>$ —</td><td>$ —</td><td></td></tr><tr><td>Level 3:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource</td><td>(376.9)</td><td>—</td><td>(376.9)</td><td>(413.7)</td><td>—</td><td>(413.7)</td><td></td></tr><tr><td>CL&amp;P</td><td>(376.9)</td><td>—</td><td>(376.9)</td><td>(412.8)</td><td>—</td><td>(412.8)</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, 2017, CL&P's derivative assets were exposed to counterparty credit risk. Of CL&P's derivative assets, $69.0 million was 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 capacity of these contracts is 787 MW. 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, 2017 and 2016, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of 9.5 million and 9.2 million MMBtu of natural gas, respectively.

For the years ended December 31, 2017, 2016 and 2015, there were losses of $29.0 million, $125.5 million and $60.2 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource's derivative contracts.

## Credit Risk

Certain of Eversource's derivative contracts contain credit risk contingent provisions. These provisions require Eversource to maintain investment grade credit ratings from the major rating agencies and to post collateral for contracts in a net liability position over specified credit limits. As of December 31, 2017, Eversource had $3.4 million of derivative contracts in a net liability position that were subject to credit risk contingent provisions and would have been required to post additional collateral of $3.7 million if Eversource's unsecured debt credit ratings had been downgraded to below investment grade. As of December 31, 2016, Eversource had no derivative contracts in a net liability position that were subject to credit risk contingent provisions.

## 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 power and 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 CL&P's 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">2017</td><td colspan="4">2016</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>$ 5.00</td><td>—</td><td>8.70</td><td>per kW-Month</td><td>$ 5.50</td><td>—</td><td>8.70</td><td>per kW-Month</td></tr><tr><td>Forward Reserve</td><td>1.00</td><td>—</td><td>2.00</td><td>per kW-Month</td><td>2018 - 2024</td><td>1.40</td><td>—</td><td>2.00</td></tr></table>

Exit price premiums of 6 percent through 18 percent are also applied on 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.

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>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td></tr><tr><td>Derivatives, Net:</td><td></td><td></td></tr><tr><td>Fair Value as of January 1, 2016</td><td>$ (380.9)</td><td>$ (380.8)</td></tr><tr><td>Net Realized/Unrealized Losses Included in Regulatory Assets and Liabilities</td><td>(130.7)</td><td>(122.7)</td></tr><tr><td>Settlements</td><td>88.3</td><td>83.0</td></tr><tr><td>Fair Value as of December 31, 2016</td><td>$ (423.3)</td><td>$ (420.5)</td></tr><tr><td>Transfer out of Level 3</td><td>1.2</td><td>—</td></tr><tr><td>Net Realized/Unrealized Losses Included in Regulatory Assets and Liabilities</td><td>(11.4)</td><td>(9.5)</td></tr><tr><td>Settlements</td><td>71.2</td><td>67.7</td></tr><tr><td>Fair Value as of December 31, 2017</td><td>$ (362.3)</td><td>$ (362.3)</td></tr></table>

Significant increases or decreases in future energy or capacity 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.



## 5. MARKETABLE SECURITIES

Eversource maintains trusts that hold marketable securities to fund certain non-qualified executive benefits. These trusts 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.

Trading Securities: Eversource has elected to record certain equity securities as trading securities, with the changes in fair values recorded in Other Income, Net on the statements of income. As of December 31, 2016, these securities were classified as Level 1 in the fair value hierarchy and totaled $9.6 million. These securities were sold during 2017 and were no longer held as of December 31, 2017. For the years ended December 31, 2016 and 2015, net gains on these securities of $0.6 million and $2.0 million, respectively, were recorded in Other Income, Net on the statements of income. Dividend income is recorded in Other Income, Net when dividends are declared.

Available-for-Sale Securities: The following is a summary of available-for-sale 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">Eversource (Millions of Dollars)</td><td colspan="4">2017</td><td colspan="4">2016</td></tr><tr><td>Amortized Cost</td><td>Pre-Tax Unrealized Gains</td><td>Pre-Tax Unrealized Losses</td><td>Fair Value</td><td>Amortized Cost</td><td>Pre-Tax Unrealized Gains</td><td>Pre-Tax Realized Losses</td><td>Fair Value</td></tr><tr><td>Debt Securities</td><td>$ 284.9</td><td>$ 3.2</td><td>$ (1.1)</td><td>$ 287.0</td><td>$ 296.2</td><td>$ 1.1</td><td>$ (2.1)</td><td>$ 295.2</td></tr><tr><td>Equity Securities</td><td>216.1</td><td>97.8</td><td>(0.1)</td><td>313.8</td><td>203.3</td><td>62.3</td><td>(1.2)</td><td>264.4</td></tr></table>

Eversource’s debt and equity securities include CYAPC’s and YAEC’s marketable securities held in nuclear decommissioning trusts in the amounts of $503.6 million and $466.7 million as of December 31, 2017 and 2016, respectively. Unrealized gains and losses for these nuclear decommissioning trusts 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.

Unrealized Losses and Other-than-Temporary Impairment: There have been no significant unrealized losses, other-than-temporary impairments or credit losses in 2017 or 2016. 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.

Realized Gains and Losses: Realized gains and losses on available-for-sale securities 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 benefit trust, and the average cost basis method for the CYAPC and YAEC nuclear decommissioning trusts to compute the realized gains and losses on the sale of available-for-sale securities. For the year ended December 31, 2017, Eversource recognized net realized gains of $9.8 million on the sales of available-for-sale securities held in the benefit trust. The proceeds of the sales were re-invested in the Eversource benefit trust.

Contractual Maturities: As of December 31, 2017, 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>40.2</td><td>40.1</td></tr><tr><td>One to five years</td><td>46.7</td><td>47.5</td></tr><tr><td>Six to ten years</td><td>64.7</td><td>65.6</td></tr><tr><td>Greater than ten years</td><td>133.3</td><td>133.8</td></tr><tr><td>Total Debt Securities</td><td>284.9</td><td>287.0</td></tr></table>

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



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>2017</td><td>2016</td><td></td></tr><tr><td>Level 1:</td><td></td><td></td><td></td></tr><tr><td>Mutual Funds and Equities</td><td>$     313.8</td><td>$     274.0</td><td></td></tr><tr><td>Money Market Funds</td><td>23.3</td><td>54.8</td><td></td></tr><tr><td>Total Level 1</td><td>$     337.1</td><td>$     328.8</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>$     70.2</td><td>$     63.0</td><td></td></tr><tr><td>Corporate Debt Securities</td><td>50.9</td><td>41.1</td><td></td></tr><tr><td>Asset-Backed Debt Securities</td><td>21.2</td><td>18.5</td><td></td></tr><tr><td>Municipal Bonds</td><td>110.7</td><td>107.5</td><td></td></tr><tr><td>Other Fixed Income Securities</td><td>10.7</td><td>10.3</td><td></td></tr><tr><td>Total Level 2</td><td>$     263.7</td><td>$     240.4</td><td></td></tr><tr><td>Total Marketable Securities</td><td>$     600.8</td><td>$     569.2</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. 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 certain assets containing asbestos and hazardous contamination, and 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 are as follows:

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="3">As of December 31,</td></tr><tr><td>2017</td><td>2016</td><td></td></tr><tr><td>Balance as of Beginning of Year</td><td>$     426.4</td><td>$     430.1</td><td></td></tr><tr><td>Liabilities Incurred During the Year</td><td>0.2</td><td>1.3</td><td></td></tr><tr><td>Liabilities Settled During the Year</td><td>(19.3)</td><td>(19.0)</td><td></td></tr><tr><td>Accretion</td><td>26.3</td><td>22.9</td><td></td></tr><tr><td>Revisions in Estimated Cash Flows</td><td>(14.5)</td><td>(8.9)</td><td></td></tr><tr><td>Balance as of End of Year</td><td>$     419.1</td><td>$     426.4</td><td></td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="6">As of December 31,</td></tr><tr><td colspan="3">2017</td><td colspan="3">2016</td></tr><tr><td></td><td colspan="2">NSTAR</td><td colspan="2">NSTAR</td><td colspan="2">PSNH</td></tr><tr><td>(Millions of Dollars)</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td></tr><tr><td>Balance as of Beginning of Year</td><td>$   36.0</td><td>$   42.6</td><td>$   23.5</td><td>$   33.8</td><td>$   41.0</td><td>$   21.6</td></tr><tr><td>Liabilities Incurred During the Year</td><td>0.1</td><td>0.1</td><td>—</td><td>—</td><td>—</td><td>0.5</td></tr><tr><td>Liabilities Settled During the Year</td><td>(1.0)</td><td>(0.2)</td><td>—</td><td>—</td><td>(0.4)</td><td>—</td></tr><tr><td>Accretion</td><td>2.3</td><td>2.1</td><td>1.5</td><td>2.2</td><td>2.0</td><td>1.4</td></tr><tr><td>Revisions in Estimated Cash Flows</td><td>(5.9)</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Balance as of End of Year</td><td>$   31.5</td><td>$   44.6</td><td>$   25.0</td><td>$   36.0</td><td>$   42.6</td><td>$   23.5</td></tr></table>

Eversource's amounts include CYAPC and YAEC's AROs of $301.5 million and $308.6 million as of December 31, 2017 and 2016, 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. 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 assumptions used to calculate the fair value of the ARO liability are recorded with a corresponding offset to the related regulatory asset. The assets held in the CYAPC and YAEC nuclear decommissioning trusts are restricted for settling the ARO and all other decommissioning obligations. For further information on the assets held in the nuclear decommissioning trusts, see Note 5, "Marketable Securities," to the financial statements.

## 7. SHORT-TERM DEBT

Short-Term Debt Borrowing Limits: The amount of short-term borrowings that may be incurred by CL&P, NSTAR Electric and NPT 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 November 30, 2017, 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, 2019. On November 30, 2017, 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 30, 2019. On November 3, 2016, FERC authorized NPT to issue up to an aggregate of $800 million in short-term debt and long-term debt through December 31, 2018.

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, 2017, PSNH's short-term debt authorization under the 10 percent of net fixed plant test plus $60 million totaled approximately $364 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, 2017, CL&P had $607.4 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 and Yankee Gas are also parties to a five-year $1.45 billion revolving credit facility. On December 8, 2017, Eversource parent amended and restated the revolving credit facility. The amended and restated credit facility terminates on December 8, 2022 and serves to backstop Eversource parent's $1.45 billion commercial paper program. There were no borrowings outstanding on the revolving credit facility as of December 31, 2017 or 2016.

NSTAR Electric has a $650 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. On December 8, 2017, NSTAR Electric increased its commercial paper program from $450 million to $650 million. NSTAR Electric is also a party to a five-year $650 million revolving credit facility. On December 8, 2017, NSTAR Electric amended and restated the revolving credit facility, increasing it from $450 million to $650 million. The amended and restated credit facility terminates on December 8, 2022 and serves to backstop NSTAR Electric's $650 million commercial paper program. There were no borrowings outstanding on the revolving credit facility as of December 31, 2017 or 2016.

The amount of borrowings outstanding and available under the commercial paper programs and revolving credit facility was 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>2017</td><td>2016</td><td></td><td>2017</td><td>2016</td><td></td><td>2017</td><td>2016</td></tr><tr><td>Eversource Parent Commercial Paper Program</td><td>$ 979.3</td><td>$ 1,022.0</td><td>$ 470.7</td><td>$ 428.0</td><td></td><td>1.86%</td><td>0.88%</td><td></td></tr><tr><td>NSTAR Electric Commercial Paper Program</td><td>234.0</td><td>126.5</td><td>416.0</td><td>323.5</td><td></td><td>1.55%</td><td>0.71%</td><td></td></tr><tr><td>Revolving Credit Facility (1)</td><td>76.0</td><td>N/A</td><td>24.0</td><td>N/A</td><td>2.66%</td><td>N/A</td><td></td><td></td></tr></table>

(1) Aquarion has a $100.0 million revolving credit facility, which expires on August 19, 2019.

Amounts outstanding under the commercial paper programs and revolving credit facility are included in Notes Payable for Eversource and NSTAR Electric and are classified in current liabilities on the 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 issuances on January 8, 2018, the net proceeds of which were used to repay short-term borrowings outstanding under its commercial paper program, $201.2 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified as Long-Term Debt as of December 31, 2017.

As of December 31, 2017, there were intercompany loans from Eversource parent of $69.5 million to CL&P and $262.9 million to PSNH. As of December 31, 2016, there were intercompany loans from Eversource parent of $80.1 million to CL&P, $160.9 million to PSNH and $51.0 million to NSTAR Electric. These intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and are classified in current liabilities on the respective subsidiary's balance sheets. Intercompany loans from Eversource parent are eliminated in consolidation on Eversource's balance sheets.

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, 2017 and 2016, 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.



## 8. LONG-TERM DEBT

Details of long-term debt outstanding are as follows:

<table><tr><td rowspan="2">CL&amp;P(Millions of Dollars)First Mortgage Bonds:</td><td colspan="2">As of December 31,</td></tr><tr><td>2017</td><td>2016</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>5.375% 2007 Series A due 2017</td><td>—</td><td>150.0</td></tr><tr><td>5.750% 2007 Series B due 2037</td><td>150.0</td><td>150.0</td></tr><tr><td>5.750% 2007 Series C due 2017</td><td>—</td><td>100.0</td></tr><tr><td>6.375% 2007 Series D due 2037</td><td>100.0</td><td>100.0</td></tr><tr><td>5.650% 2008 Series A due 2018</td><td>300.0</td><td>300.0</td></tr><tr><td>5.500% 2009 Series A due 2019</td><td>250.0</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>250.0</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>300.0</td><td>—</td></tr><tr><td>Total First Mortgage Bonds</td><td>2,944.8</td><td>2,669.8</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>(300.0)</td><td>(250.0)</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>11.5</td><td>(10.0)</td></tr><tr><td>Unamortized Debt Issuance Costs</td><td>(17.7)</td><td>(14.3)</td></tr><tr><td>CL&amp;P Long-Term Debt</td><td>$ 2,759.1</td><td>$ 2,516.0</td></tr></table>

<table><tr><td rowspan="2">NSTAR Electric(Millions of Dollars)Debentures:</td><td colspan="2">As of December 31,</td></tr><tr><td>2017</td><td>2016</td></tr><tr><td>5.750% due 2036</td><td>$ 200.0</td><td>$ 200.0</td></tr><tr><td>5.625% due 2017</td><td>—</td><td>400.0</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>—</td></tr><tr><td>Total Debentures</td><td>2,400.0</td><td>2,100.0</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>—</td><td>(400.0)</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>(1.8)</td><td>(4.9)</td></tr><tr><td>Unamortized Debt Issuance Costs</td><td>(19.4)</td><td>(15.5)</td></tr><tr><td>NSTAR Electric Long-Term Debt</td><td>$ 2,943.8</td><td>$ 2,244.6</td></tr></table>



<table><tr><td rowspan="2">PSNH(Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2017</td><td>2016</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>6.150% Series N due 2017</td><td>—</td><td>70.0</td></tr><tr><td>6.000% Series O due 2018</td><td>110.0</td><td>110.0</td></tr><tr><td>4.500% Series P due 2019</td><td>150.0</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>Total First Mortgage Bonds</td><td>917.0</td><td>987.0</td></tr><tr><td>Pollution Control Revenue Bonds:</td><td></td><td></td></tr><tr><td>Adjustable Rate Tax Exempt Series A due 2021(2.048% and 1.138% as of December 31, 2017 and 2016, respectively)</td><td>89.3</td><td>89.3</td></tr><tr><td>Less Amounts due Within One Year</td><td>(110.0)</td><td>(70.0)</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>0.2</td><td>0.1</td></tr><tr><td>Unamortized Debt Issuance Costs</td><td>(4.1)</td><td>(4.4)</td></tr><tr><td>PSNH Long-Term Debt</td><td>$ 892.4</td><td>$ 1,002.0</td></tr></table>

<table><tr><td rowspan="2">OTHER(Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2017</td><td>2016</td></tr><tr><td>Yankee Gas - First Mortgage Bonds: 3.020% - 8.480% due 2018 - 2044</td><td>$ 520.0</td><td>$ 445.0</td></tr><tr><td>NSTAR Gas - First Mortgage Bonds: 4.350% - 9.950% due 2020 - 2045</td><td>285.0</td><td>310.0</td></tr><tr><td>Eversource Parent and Other - Notes and Debentures:</td><td></td><td></td></tr><tr><td>4.500% Debentures due 2019</td><td>350.0</td><td>350.0</td></tr><tr><td>1.450% - 4.000% Senior Notes due 2018 - 2026</td><td>3,260.0</td><td>1,700.0</td></tr><tr><td>Notes Payable Unsecured 3.57% - 6.430% due 2021 - 2037</td><td>290.9</td><td>—</td></tr><tr><td>Notes Payable Secured 4.10% - 9.64% due 2021 - 2035</td><td>70.4</td><td>—</td></tr><tr><td>Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)</td><td>181.4</td><td>180.0</td></tr><tr><td>Fair Value Adjustment \( ^{(1)} \)</td><td>172.6</td><td>144.6</td></tr><tr><td>Less Fair Value Adjustment - Current Portion \( ^{(1)} \)</td><td>(35.4)</td><td>(28.9)</td></tr><tr><td>Less Amounts due in One Year</td><td>(104.2)</td><td>(25.0)</td></tr><tr><td>Commercial Paper Classified as Long-Term Debt</td><td>201.2</td><td>—</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>1.5</td><td>(1.8)</td></tr><tr><td>Unamortized Debt Issuance Costs</td><td>(12.8)</td><td>(7.1)</td></tr><tr><td>Total Other Long-Term Debt</td><td>5,180.6</td><td>3,066.8</td></tr><tr><td>Total Eversource Long-Term Debt</td><td>11,775.9</td><td>8,829.4</td></tr></table>

(1) The fair value adjustment amount is the purchase price adjustment, net of amortization, required to record the NSTAR long-term debt at fair value on the date of the 2012 merger and to record the Aquarion long-term debt at fair value as of December 4, 2017.



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>Issuances/Repayments)</td><td>Maturity Date</td><td>Use of Proceeds</td></tr><tr><td>CL&amp;P:</td><td></td><td></td><td></td><td></td></tr><tr><td>3.20% 2017 Series A First Mortgage Bonds</td><td>March 2017</td><td>$ 300.0</td><td>2027</td><td>Repay short-term debt borrowings</td></tr><tr><td>4.30% 2014 Series A First Mortgage Bonds (1)</td><td>August 2017</td><td>225.0</td><td>2044</td><td>Refinance short-term debt and fund working capital and capital expenditures</td></tr><tr><td>5.375% 2007 Series A First Mortgage Bonds</td><td>March 2007</td><td>(150.0)</td><td>2017</td><td>N/A</td></tr><tr><td>5.75% 2007 Series C First Mortgage Bonds</td><td>September 2007</td><td>(100.0)</td><td>2017</td><td>N/A</td></tr><tr><td>NSTAR Electric:</td><td></td><td></td><td></td><td></td></tr><tr><td>3.20% Debentures</td><td>May 2017</td><td>350.0</td><td>2027</td><td>Repay short-term borrowings and fund capital expenditures and working capital</td></tr><tr><td>3.20% Debentures (2)</td><td>October 2017</td><td>350.0</td><td>2027</td><td>Redeem long-term debt that matured in 2017</td></tr><tr><td>5.625% Debentures</td><td>November 2007</td><td>(400.0)</td><td>2017</td><td>N/A</td></tr><tr><td>PSNH:</td><td></td><td></td><td></td><td></td></tr><tr><td>6.15% Series N First Mortgage Bonds</td><td>September 2007</td><td>(70.0)</td><td>2017</td><td>N/A</td></tr><tr><td>Other:</td><td></td><td></td><td></td><td></td></tr><tr><td>Yankee Gas 3.02% Series N First Mortgage Bonds</td><td>September 2017</td><td>75.0</td><td>2027</td><td>Repay short-term borrowings</td></tr><tr><td>NSTAR Gas 7.04% Series M First Mortgage Bonds</td><td>September 1997</td><td>(25.0)</td><td>2017</td><td>N/A</td></tr><tr><td>Eversource Parent 2.75% Series K Senior Notes</td><td>March 2017</td><td>300.0</td><td>2022</td><td>Repay short-term borrowings</td></tr><tr><td>Eversource Parent 2.75% Series K Senior Notes (3)</td><td>October 2017</td><td>450.0</td><td>2022</td><td>Repay short-term borrowings</td></tr><tr><td>Eversource Parent 2.90% Series L Senior Notes</td><td>October 2017</td><td>450.0</td><td>2024</td><td>Repay short-term borrowings</td></tr><tr><td>Eversource Parent 2.50% Series I Senior Notes (4)</td><td>January 2018</td><td>200.0</td><td>2021</td><td>Repay long-term debt due to mature in 2018 and repay short-term borrowings</td></tr><tr><td>Eversource Parent 3.30% Series M Senior Notes</td><td>January 2018</td><td>450.0</td><td>2028</td><td>Repay long-term debt due to mature in 2018</td></tr><tr><td>Eversource Parent 1.60% Series G Senior Notes (5)</td><td>January 2015</td><td>(150.0)</td><td>2018</td><td>N/A</td></tr></table>

(1) These bonds are part of the existing series initially issued by CL&P in 2014. The aggregate outstanding principal amount for these bonds is now $475 million.

(2) These debentures are part of the same series initially issued by NSTAR Electric in May 2017. The aggregate outstanding principal amount for these debentures is now $700 million.

(3) These notes are part of the same series issued by Eversource parent in March 2017. The aggregate outstanding principal amount for these notes is now $750 million.

(4) These notes are part of the same series issued by Eversource parent in March 2016. The aggregate outstanding principal amount for these notes is now $450 million.

(5) Represents a repayment at maturity on January, 15 2018.

As a result of the Eversource parent debt issuances in January 2018, $446.8 million of current portion of long-term debt related to two Eversource parent issuances maturing in 2018 and $201.2 million of commercial paper borrowings were reclassified to Long-Term Debt as of December 31, 2017.

Long-Term Debt Issuance Authorizations: On January 4, 2017, PURA approved CL&P's request for authorization to issue up to $1.325 billion in long-term debt through December 31, 2020. On March 30, 2017, the DPU approved NSTAR Electric's request for authorization to issue up to $700 million in long-term debt through December 31, 2018. On December 20, 2017, PURA approved Yankee Gas' request to extend the authorization period for issuance of up to $50 million in long-term debt from December 31, 2017 to December 31, 2018.

Long-Term Debt Provisions: The utility plant of CL&P, PSNH, Yankee Gas and NSTAR Gas is subject to the lien of each company's respective first mortgage bond indenture. The Eversource parent and NSTAR Electric 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 and NSTAR Gas. Under the equity requirements, NSTAR Electric'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 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. All other long-term debt securities are subject to make-whole provisions.

PSNH's obligation to repay the PCRBs is secured by first mortgage bonds and bond insurance. The first mortgage bonds contain similar terms and provisions as the PCRBs. If PSNH 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. The PSNH Series A tax-exempt PCRBs are currently callable at 100 percent of par. The PCRBs bear interest at a rate that is periodically set pursuant to auctions. PSNH is not obligated to purchase these PCRBs, which mature in 2021, from the remarketing agent.

Certain secured and unsecured notes payable are callable at redemption price and are subject to make-whole provisions.



Eversource, NSTAR Electric and Yankee Gas have certain long-term debt agreements that contain cross-default provisions. No other debt issuances contain cross-default provisions as of December 31, 2017.

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, 2017 and 2016, as a result of consolidating CYAPC, Eversource has consolidated $181.4 million and $180.0 million, respectively, in pre-1983 spent nuclear fuel obligations to the DOE. These obligations include accumulated interest costs of $132.6 million and $131.2 million as of December 31, 2017 and 2016, 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 2018 through 2022 and thereafter are shown below. These amounts exclude the CYAPC pre-1983 spent nuclear fuel obligation, net unamortized premiums, discounts and debt issuance costs, and other fair value adjustments as of December 31, 2017:

<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>2018</td><td>$ 961.0</td><td>$ 300.0</td><td>$ —</td><td>$ 110.0</td></tr><tr><td>2019</td><td>801.0</td><td>250.0</td><td>—</td><td>150.0</td></tr><tr><td>2020</td><td>296.1</td><td>—</td><td>95.0</td><td>—</td></tr><tr><td>2021</td><td>922.8</td><td>—</td><td>250.0</td><td>371.3</td></tr><tr><td>2022</td><td>1,188.9</td><td>—</td><td>400.0</td><td>—</td></tr><tr><td>Thereafter</td><td>7,643.1</td><td>2,515.3</td><td>2,220.0</td><td>375.0</td></tr><tr><td>Total</td><td>$ 11,812.9</td><td>$ 3,065.3</td><td>$ 2,965.0</td><td>$ 1,006.3</td></tr></table>

## 9. EMPLOYEE BENEFITS

## A. Pension Benefits and Postretirement Benefits Other Than Pensions

Eversource provides defined benefit plans (the "Pension Plans") that cover eligible employees, including, among others, employees of CL&P, NSTAR Electric and PSNH. The Pension Plans are subject to the provisions of ERISA, as amended by the PPA 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 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 (the "PBOP Plans") that provided certain benefits, primarily medical, dental and life insurance to eligible employees that met certain age and service eligibility requirements. In August 2016, Eversource Service amended its PBOP Plan, which standardized separate benefit structures that existed within the plan and made other benefit changes. The new plan provides life insurance and a health reimbursement arrangement created for the purpose of reimbursing retirees and dependents for health insurance premiums and certain medical expenses. 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.

Because the regulated companies recover the retiree benefit costs from customers through rates, regulatory assets are recorded in lieu of recording an adjustment to Accumulated Other Comprehensive Income/(Loss) for the funded status of the Pension, SERP and PBOP Plans. Regulatory accounting is also applied to the portions of the Eversource Service costs that support the regulated companies, as these costs are also recovered from customers. Adjustments to the Pension 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 15, "Accumulated Other Comprehensive Income/(Loss)," to the financial statements.

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 unrecognized actuarial gains or losses, which are recorded in Regulatory Assets or Accumulated Other Comprehensive Income/(Loss). Unrecognized actuarial gains or losses are amortized as a component of pension and PBOP expense over the estimated average future employee service period.



Pension and SERP Plans: The Pension and SERP 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 table provides information on the Pension and SERP Plan benefit obligations, fair values of Pension Plan assets, and funded status:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="10">Pension and SERP</td></tr><tr><td colspan="5">As of December 31, 2017</td><td colspan="5">As of December 31, 2016</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><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>$ (5,242.3)</td><td>$ (1,170.2)</td><td>$ (1,217.3)</td><td>$ (572.2)</td><td>$ (5,080.1)</td><td>$ (1,157.6)</td><td>$ (1,187.3)</td><td>$ (547.6)</td><td></td><td></td></tr><tr><td>Plan Amendment</td><td>—</td><td>—</td><td>—</td><td>—</td><td>(9.0)</td><td>—</td><td>(2.8)</td><td>—</td><td></td><td></td></tr><tr><td>Employee Transfers</td><td>—</td><td>8.2</td><td>5.5</td><td>(0.7)</td><td>—</td><td>8.8</td><td>1.3</td><td>2.4</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>(75.0)</td><td>(18.8)</td><td>(16.3)</td><td>(9.9)</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>(185.5)</td><td>(41.6)</td><td>(42.2)</td><td>(20.7)</td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>(548.7)</td><td>(116.9)</td><td>(143.5)</td><td>(65.1)</td><td>(151.8)</td><td>(23.9)</td><td>(37.2)</td><td>(21.5)</td><td></td><td></td></tr><tr><td>Benefits Paid - Pension</td><td>243.7</td><td>63.5</td><td>55.4</td><td>26.4</td><td>254.0</td><td>62.6</td><td>67.0</td><td>24.9</td><td></td><td></td></tr><tr><td>Benefits Paid - Lump Sum</td><td>18.4</td><td>—</td><td>6.8</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td></td><td></td></tr><tr><td>Benefits Paid - SERP</td><td>20.4</td><td>0.3</td><td>0.3</td><td>0.3</td><td>5.1</td><td>0.3</td><td>0.2</td><td>0.2</td><td></td><td></td></tr><tr><td>Increase due to acquisition of Aquarion</td><td>(168.7)</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 End of Year</td><td>$ (5,936.5)</td><td>$ (1,275.2)</td><td>$ (1,351.0)</td><td>$ (642.2)</td><td>$ (5,242.3)</td><td>$ (1,170.2)</td><td>$ (1,217.3)</td><td>$ (572.2)</td><td></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><td></td></tr><tr><td>Fair Value of Pension Plan Assets as of Beginning of Year</td><td>$ 4,076.0</td><td>$ 905.5</td><td>$ 1,088.3</td><td>$ 494.0</td><td>$ 3,905.4</td><td>$ 913.5</td><td>$ 1,053.7</td><td>$ 470.5</td><td></td><td></td></tr><tr><td>Employee Transfers</td><td>—</td><td>(8.2)</td><td>(5.5)</td><td>0.7</td><td>—</td><td>(8.8)</td><td>(1.3)</td><td>(2.4)</td><td></td><td></td></tr><tr><td>Employer Contributions</td><td>235.2</td><td>2.5</td><td>85.4</td><td>0.8</td><td>146.2</td><td>0.4</td><td>28.4</td><td>17.1</td><td></td><td></td></tr><tr><td>Actual Return on Pension Plan Assets</td><td>589.7</td><td>126.7</td><td>154.8</td><td>70.4</td><td>278.4</td><td>63.0</td><td>74.5</td><td>33.7</td><td></td><td></td></tr><tr><td>Benefits Paid</td><td>(243.7)</td><td>(63.5)</td><td>(55.4)</td><td>(26.4)</td><td>(254.0)</td><td>(62.6)</td><td>(67.0)</td><td>(24.9)</td><td></td><td></td></tr><tr><td>Benefits Paid - Lump Sum</td><td>(18.4)</td><td>—</td><td>(6.8)</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td></td><td></td></tr><tr><td>Increase due to acquisition of Aquarion</td><td>100.7</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 End of Year</td><td>$ 4,739.5</td><td>$ 963.0</td><td>$ 1,260.8</td><td>$ 539.5</td><td>$ 4,076.0</td><td>$ 905.5</td><td>$ 1,088.3</td><td>$ 494.0</td><td></td><td></td></tr><tr><td>Funded Status as of December 31st</td><td>$ (1,197.0)</td><td>$ (312.2)</td><td>$ (90.2)</td><td>$ (102.7)</td><td>$ (1,166.3)</td><td>$ (264.7)</td><td>$ (129.0)</td><td>$ (78.2)</td><td></td><td></td></tr></table>

In 2017, there was a decrease to the discount rate used to calculate the funded status of the Eversource pension liability, which resulted in an increase to Eversource's pension liability of approximately $390 million as of December 31, 2017.

In 2016, there was a decrease in the discount rate used to calculate the funded status of the Eversource pension liability, which resulted in an increase to Eversource's pension liability of approximately $177 million, partially offset by a revised scale for the mortality table resulting in a decrease to Eversource's pension liability of approximately $32 million as of December 31, 2016. In December 2016, Eversource amended its pension plan to adjust the calculation of lump sum payments or annuity payments for certain employees. This amendment resulted in an increase to the liability of $9 million as of December 31, 2016.

The pension and SERP Plans' funded status includes the current portion of the SERP liability totaling $8.4 million and $24.8 million as of December 31, 2017 and 2016, respectively, which is included in Other Current Liabilities on the balance sheets.

As of December 31, 2017 and 2016, 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>2017</td><td>$ 5,583.6</td><td>$ 1,179.2</td><td>$ 1,260.1</td><td>$ 597.2</td></tr><tr><td>2016</td><td>4,829.6</td><td>1,065.2</td><td>1,124.8</td><td>518.9</td></tr></table>

The following actuarial assumptions were used in calculating the Pension and SERP Plans' year end funded status:

<table><tr><td rowspan="3"></td><td colspan="3">Pension and SERP</td></tr><tr><td colspan="2">As of December 31,</td><td></td></tr><tr><td>2017</td><td>2016</td><td></td></tr><tr><td>Discount Rate</td><td>3.43% — 3.75%</td><td>4.01% — 4.33%</td><td></td></tr><tr><td>Compensation/Progression Rate</td><td>3.50% — 4.00%</td><td>3.50%</td><td></td></tr></table>



Pension and SERP Expense: Eversource charges net periodic pension expense 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.

Effective January 1, 2016, the Company refined its method of estimating the discount rate for the service and interest cost components of Pension expense from the yield-curve approach to the spot rate methodology, which provides a more precise measurement by matching projected cash flows to the corresponding spot rates on the yield curve. Historically, these components were estimated using the same weighted-average discount rate as for the funded status. The total pre-tax benefit of this change on Pension expense, prior to the capitalized portion and amounts deferred and recovered through rate reconciliation mechanisms, for the year ended December 31, 2016 was approximately $46 million.

The components of net periodic benefit expense for the Pension and SERP Plans are shown below. The net periodic benefit expense and the intercompany allocations, less the capitalized portions of pension and SERP amounts, are included in Operations and Maintenance expense on the statements of income. Capitalized amounts relate to employees working on capital projects and are included in Property, Plant and Equipment, Net on the balance sheets. Pension and SERP 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 portion, as these amounts are cash settled on a short-term basis.

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="5">Pension and SERP</td></tr><tr><td colspan="5">For the Year Ended December 31, 2017</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</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></td></tr><tr><td>Interest Cost</td><td>188.0</td><td>41.6</td><td>42.7</td><td>21.2</td><td></td></tr><tr><td>Expected Return on Pension Plan Assets</td><td>(334.1)</td><td>(71.7)</td><td>(87.6)</td><td>(40.0)</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></td></tr><tr><td>Prior Service Cost</td><td>4.5</td><td>1.5</td><td>0.6</td><td>0.5</td><td></td></tr><tr><td>Total Net Periodic Benefit Expense</td><td>$ 64.9</td><td>$ 17.6</td><td>$ 12.3</td><td>$ 3.0</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></td></tr><tr><td>Capitalized Pension Expense</td><td>$ 22.0</td><td>$ 9.7</td><td>$ 7.6</td><td>$ 1.5</td><td></td></tr></table>

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="5">Pension and SERP</td></tr><tr><td colspan="5">For the Year Ended December 31, 2016</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td></tr><tr><td>Service Cost</td><td>$ 75.0</td><td>$ 18.8</td><td>$ 16.3</td><td>$ 9.9</td><td></td></tr><tr><td>Interest Cost</td><td>185.5</td><td>41.6</td><td>42.2</td><td>20.7</td><td></td></tr><tr><td>Expected Return on Pension Plan Assets</td><td>(317.9)</td><td>(72.1)</td><td>(85.1)</td><td>(38.6)</td><td></td></tr><tr><td>Actuarial Loss</td><td>125.7</td><td>25.4</td><td>39.9</td><td>9.9</td><td></td></tr><tr><td>Prior Service Cost</td><td>3.6</td><td>1.5</td><td>0.3</td><td>0.5</td><td></td></tr><tr><td>Total Net Periodic Benefit Expense</td><td>$ 71.9</td><td>$ 15.2</td><td>$ 13.6</td><td>$ 2.4</td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 13.8</td><td>$ 11.4</td><td>$ 4.0</td><td></td></tr><tr><td>Capitalized Pension Expense</td><td>$ 22.1</td><td>$ 9.3</td><td>$ 8.0</td><td>$ 1.4</td><td></td></tr></table>

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="5">Pension and SERP</td></tr><tr><td colspan="5">For the Year Ended December 31, 2015</td></tr><tr><td>Eversource  \( {}^{(1)} \)</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH  \( {}^{(1)} \)</td><td></td></tr><tr><td>Service Cost</td><td>$ 91.4</td><td>$ 24.7</td><td>$ 19.2</td><td>$ 12.1</td><td></td></tr><tr><td>Interest Cost</td><td>227.0</td><td>51.1</td><td>50.6</td><td>24.3</td><td></td></tr><tr><td>Expected Return on Pension Plan Assets</td><td>(335.9)</td><td>(78.9)</td><td>(88.9)</td><td>(40.4)</td><td></td></tr><tr><td>Actuarial Loss</td><td>148.5</td><td>32.2</td><td>42.2</td><td>11.6</td><td></td></tr><tr><td>Prior Service Cost</td><td>3.7</td><td>1.5</td><td>0.2</td><td>0.5</td><td></td></tr><tr><td>Total Net Periodic Benefit Expense</td><td>$ 134.7</td><td>$ 30.6</td><td>$ 23.3</td><td>$ 8.1</td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 22.5</td><td>$ 18.0</td><td>$ 6.7</td><td></td></tr><tr><td>Capitalized Pension Expense</td><td>$ 41.0</td><td>$ 18.8</td><td>$ 13.3</td><td>$ 3.5</td><td></td></tr></table>

(1) Amounts exclude $3.2 million for the year ended December 31, 2015 that represent amounts included in other deferred debits.

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

<table><tr><td rowspan="3"></td><td colspan="5">Pension and SERP</td></tr><tr><td colspan="5">For the Years Ended December 31,</td></tr><tr><td colspan="2">2017</td><td colspan="2">2016</td><td>2015</td></tr><tr><td>Discount Rate</td><td>3.20%</td><td>—</td><td>3.90%</td><td>3.27%</td><td>4.89%</td></tr><tr><td>Expected Long-Term Rate of Return</td><td>8.25%</td><td></td><td></td><td>8.25%</td><td></td></tr><tr><td>Compensation/Progression Rate</td><td>3.50%</td><td></td><td></td><td>3.50%</td><td></td></tr></table>



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="2"></td><td colspan="3">Regulatory Assets</td><td colspan="3">OCI</td></tr><tr><td colspan="6">For the Years Ended December 31,</td></tr><tr><td>(Millions of Dollars)</td><td>2017</td><td>2016</td><td>2017</td><td>2016</td><td></td><td></td></tr><tr><td>Actuarial Losses Arising During the Year</td><td>$ 333.0</td><td>$ 184.6</td><td>$ 9.3</td><td>$ 6.8</td><td></td><td></td></tr><tr><td>Actuarial Losses Reclassified as Net Periodic Benefit Expense</td><td>(129.5)</td><td>(119.9)</td><td>(5.7)</td><td>(5.8)</td><td></td><td></td></tr><tr><td>Prior Service Cost/(Credit) Arising During the Year</td><td>1.0</td><td>7.1</td><td>(0.4)</td><td>1.9</td><td></td><td></td></tr><tr><td>Prior Service Cost Reclassified as Net Periodic Benefit Expense</td><td>(4.1)</td><td>(3.4)</td><td>(0.4)</td><td>(0.2)</td><td></td><td></td></tr></table>

The following is a summary of the remaining Regulatory Assets and Accumulated Other Comprehensive Loss amounts that have not been recognized as components of net periodic benefit expense as of December 31, 2017 and 2016, as well as the amounts that are expected to be recognized as components in 2018:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">Regulatory Assets as of December 31,</td><td rowspan="2">Expected 2018 Expense</td><td colspan="3">AOCL as of December 31,</td><td rowspan="2">Expected 2018 Expense</td></tr><tr><td>2017</td><td>2016</td><td></td><td>2017</td><td>2016</td><td></td></tr><tr><td>Actuarial Loss</td><td>$ 1,935.8</td><td>$ 1,732.3</td><td>$ 141.8</td><td>$ 85.7</td><td>$ 82.1</td><td>$ 5.8</td><td></td><td></td></tr><tr><td>Prior Service Cost</td><td>10.3</td><td>13.4</td><td>4.2</td><td>1.5</td><td>2.3</td><td>0.3</td><td></td><td></td></tr></table>

PBOP Plans: The 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. The following table provides information on the PBOP Plan benefit obligations, fair values of plan assets, and funded status:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="10">PBOP</td></tr><tr><td colspan="10">As of December 31,</td></tr><tr><td colspan="5">2017</td><td colspan="5">2016</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>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>$ (810.0)</td><td>$ (165.0)</td><td>$ (270.0)</td><td>$ (89.7)</td><td>$ (1,051.4)</td><td>$ (164.0)</td><td>$ (447.2)</td><td>$ (88.5)</td><td></td><td></td></tr><tr><td>Plan Amendment</td><td>—</td><td>—</td><td>—</td><td>—</td><td>244.0</td><td>(12.5)</td><td>193.6</td><td>(6.7)</td><td></td><td></td></tr><tr><td>Employee Transfers</td><td>—</td><td>2.4</td><td>1.5</td><td>0.2</td><td>—</td><td>1.3</td><td>0.5</td><td>0.3</td><td></td><td></td></tr><tr><td>Service Cost</td><td>(9.5)</td><td>(1.9)</td><td>(1.7)</td><td>(1.3)</td><td>(12.2)</td><td>(2.0)</td><td>(3.4)</td><td>(1.3)</td><td></td><td></td></tr><tr><td>Interest Cost</td><td>(27.1)</td><td>(5.3)</td><td>(8.7)</td><td>(3.0)</td><td>(32.9)</td><td>(5.3)</td><td>(13.3)</td><td>(2.9)</td><td></td><td></td></tr><tr><td>Actuarial Gain/(Loss)</td><td>(81.8)</td><td>(18.5)</td><td>(13.2)</td><td>(11.9)</td><td>(17.7)</td><td>3.6</td><td>(23.5)</td><td>3.6</td><td></td><td></td></tr><tr><td>Benefits Paid</td><td>41.5</td><td>9.9</td><td>13.5</td><td>4.6</td><td>60.2</td><td>13.9</td><td>23.3</td><td>5.8</td><td></td><td></td></tr><tr><td>Increase due to acquisition of Aquarion</td><td>(61.7)</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 End of Year</td><td>$ (948.6)</td><td>$ (178.4)</td><td>$ (278.6)</td><td>$ (101.1)</td><td>$ (810.0)</td><td>$ (165.0)</td><td>$ (270.0)</td><td>$ (89.7)</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>$ 815.8</td><td>$ 129.2</td><td>$ 361.6</td><td>$ 73.2</td><td>$ 812.2</td><td>$ 136.7</td><td>$ 352.0</td><td>$ 75.8</td><td></td><td></td></tr><tr><td>Employee Transfers</td><td>—</td><td>(1.5)</td><td>(0.8)</td><td>—</td><td>—</td><td>(0.8)</td><td>(0.6)</td><td>(0.2)</td><td></td><td></td></tr><tr><td>Actual Return on Plan Assets</td><td>118.0</td><td>18.1</td><td>52.9</td><td>10.4</td><td>51.3</td><td>7.2</td><td>24.6</td><td>3.4</td><td></td><td></td></tr><tr><td>Employer Contributions</td><td>7.6</td><td>—</td><td>5.3</td><td>—</td><td>12.5</td><td>—</td><td>8.9</td><td>—</td><td></td><td></td></tr><tr><td>Benefits Paid</td><td>(41.5)</td><td>(9.9)</td><td>(13.5)</td><td>(4.6)</td><td>(60.2)</td><td>(13.9)</td><td>(23.3)</td><td>(5.8)</td><td></td><td></td></tr><tr><td>Increase due to acquisition of Aquarion</td><td>22.3</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 End of Year</td><td>$ 922.2</td><td>$ 135.9</td><td>$ 405.5</td><td>$ 79.0</td><td>$ 815.8</td><td>$ 129.2</td><td>$ 361.6</td><td>$ 73.2</td><td></td><td></td></tr><tr><td>Funded Status as of December 31st</td><td>$ (26.4)</td><td>$ (42.5)</td><td>$ 126.9</td><td>$ (22.1)</td><td>$ 5.8</td><td>$ (35.8)</td><td>$ 91.6</td><td>$ (16.5)</td><td></td><td></td></tr></table>

The Eversource funded status includes a prepaid asset of $13.1 million recorded in Other Long-Term Assets and a liability of $39.5 million included in Accrued Pension, SERP and PBOP on the balance sheet.

As of December 31, 2017, there was a decrease in the discount rate used to calculate the funded status, as compared to the discount rate as of December 31, 2016, resulting in an increase to the Eversource PBOP liability of approximately $64 million.

The August 2016 PBOP plan amendment resulted in a reduction to Eversource's accumulated benefit liability of approximately $244 million. As of December 31, 2016, there was a decrease in the discount rate used to calculate the funded status, as compared to the discount rate as of December 31, 2015, resulting in an increase to the Eversource liability of approximately $75 million, which was partially offset by a decrease of approximately $52 million from changes in mortality and other assumptions.



The following actuarial assumptions were used in calculating the PBOP Plans' year end funded status:

<table><tr><td rowspan="4">Discount Rate</td><td colspan="3">PBOP</td></tr><tr><td colspan="3">As of December 31,</td></tr><tr><td colspan="2">2017</td><td>2016</td></tr><tr><td>3.55%</td><td>—</td><td>3.70%</td></tr></table>

For the Eversource Service PBOP Plan, effective with the plan amendment that standardized plan designs and made benefit changes in August 2016, the health care cost trend rate is no longer applicable.

PBOP Expense: Eversource charges net periodic postretirement benefits expense to its subsidiaries based on the actual participant demographic data for each subsidiary's participants. The actual investment return in the trust each year is allocated to each of the subsidiaries annually in proportion to the investment return expected to be earned during the year.

Effective January 1, 2016, the Company refined its method of estimating the discount rate for the service and interest cost components of PBOP expense from the yield-curve methodology to the spot rate methodology, which provides a more precise measurement by matching projected cash flows to the corresponding spot rates on the yield curve. Historically these components were estimated using the same weighted-average discount rate as for the funded status. The total pre-tax benefit of this change on PBOP expense, prior to the capitalized portion and amounts deferred and recovered through rate reconciliation mechanisms, for the year ended December 31, 2016 was approximately $10 million.

The August 2016 PBOP Plan amendment resulted in a remeasurement of the benefit obligation and annual expense using assumptions at that point in time, including updated discount rates and asset values. The remeasurement resulted in a decrease in net periodic benefit costs for PBOP benefits, prior to the capitalized portion and amounts deferred and recovered through rate reconciliation mechanisms, of approximately $10 million, which was recorded in 2016, and most of this amount will be deferred for future refund to customers.

The components of net periodic benefit expense for the PBOP Plans are shown below. The net periodic benefit expense and the intercompany allocations, less the capitalized portion of PBOP, are included in Operations and Maintenance expense on the statements of income. Capitalized PBOP amounts relate to employees working on capital projects and are included in Property, Plant and Equipment, Net on the balance sheets. 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 portion, as these amounts are cash settled on a short-term basis.

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">PBOP</td></tr><tr><td colspan="5">For the Year Ended December 31, 2017</td></tr><tr><td></td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td></tr><tr><td>Service Cost</td><td>$ 9.5</td><td>$ 1.9</td><td>$ 1.7</td><td>$ 1.3</td><td></td></tr><tr><td>Interest Cost</td><td>27.1</td><td>5.3</td><td>8.7</td><td>3.0</td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(63.7)</td><td>(9.7)</td><td>(28.6)</td><td>(5.5)</td><td></td></tr><tr><td>Actuarial Loss</td><td>9.1</td><td>1.0</td><td>3.4</td><td>0.6</td><td></td></tr><tr><td>Prior Service (Credit)/Cost</td><td>(21.6)</td><td>1.1</td><td>(17.0)</td><td>0.6</td><td></td></tr><tr><td>Total Net Periodic Benefit Expense/(Income)</td><td>$ (39.6)</td><td>$ (0.4)</td><td>$ (31.8)</td><td>$ —</td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ (0.7)</td><td>$ (1.1)</td><td>$ (0.5)</td><td></td></tr><tr><td>Capitalized PBOP Expense/(Income)</td><td>$ (19.1)</td><td>$ (0.5)</td><td>$ (16.2)</td><td>$ 0.2</td><td></td></tr></table>

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">PBOP</td></tr><tr><td colspan="5">For the Year Ended December 31, 2016</td></tr><tr><td></td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td></tr><tr><td>Service Cost</td><td>$ 12.2</td><td>$ 2.0</td><td>$ 3.4</td><td>$ 1.3</td><td></td></tr><tr><td>Interest Cost</td><td>32.9</td><td>5.3</td><td>13.3</td><td>2.9</td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(62.9)</td><td>(10.1)</td><td>(28.1)</td><td>(5.5)</td><td></td></tr><tr><td>Actuarial Loss</td><td>9.0</td><td>1.5</td><td>3.3</td><td>0.7</td><td></td></tr><tr><td>Prior Service (Credit)/Cost</td><td>(9.1)</td><td>0.5</td><td>(7.1)</td><td>0.2</td><td></td></tr><tr><td>Total Net Periodic Benefit Income</td><td>$ (17.9)</td><td>$ (0.8)</td><td>$ (15.2)</td><td>$ (0.4)</td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 0.3</td><td>$ (0.1)</td><td>$ (0.1)</td><td></td></tr><tr><td>Capitalized PBOP Expense/(Income)</td><td>$ (8.0)</td><td>$ (0.5)</td><td>$ (6.7)</td><td>$ 0.1</td><td></td></tr></table>



<table><tr><td rowspan="2"></td><td colspan="6">PBOP</td></tr><tr><td colspan="6">For the Year Ended December 31, 2015</td></tr><tr><td></td><td colspan="3">Eversource</td><td colspan="3">NSTAR Electric</td></tr><tr><td>(Millions of Dollars)</td><td></td><td>CL&amp;P</td><td></td><td></td><td></td><td>PSNH</td></tr><tr><td>Service Cost</td><td>$     16.3</td><td>$     2.1</td><td>$     5.8</td><td>$     1.4</td><td></td><td></td></tr><tr><td>Interest Cost</td><td>47.2</td><td>7.2</td><td>20.5</td><td>3.9</td><td></td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(67.4)</td><td>(11.1)</td><td>(29.8)</td><td>(6.0)</td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>6.8</td><td>0.7</td><td>2.3</td><td>0.5</td><td></td><td></td></tr><tr><td>Prior Service Credit</td><td>(0.5)</td><td>—</td><td>(0.2)</td><td>—</td><td></td><td></td></tr><tr><td>Total Net Periodic Benefit Expense/(Income)</td><td>$     2.4</td><td>$      (1.1)</td><td>$      (1.4)</td><td>$      (0.2)</td><td></td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$     1.9</td><td>$     1.1</td><td>$     0.4</td><td></td><td></td></tr><tr><td>Capitalized PBOP Expense/(Income)</td><td>$     0.1</td><td>$      (0.2)</td><td>$      (0.4)</td><td>$     0.2</td><td></td><td></td></tr></table>

The following actuarial assumptions were used to calculate PBOP expense amounts:

<table><tr><td rowspan="3"></td><td colspan="6">PBOP</td></tr><tr><td colspan="6">For the Years Ended December 31,</td></tr><tr><td colspan="2">2017</td><td colspan="2">2016</td><td colspan="2">2015</td></tr><tr><td>Discount Rate</td><td>3.48%</td><td>4.64%</td><td>2.88%</td><td>4.09%</td><td>4.22%</td><td></td></tr><tr><td>Expected Long-Term Rate of Return</td><td>8.25%</td><td></td><td>8.25%</td><td></td><td>8.25%</td><td></td></tr></table>

The health care cost trend rate assumption used to calculate the PBOP expense amount for the Eversource PBOP Plan was 6.25 percent and 6.5 percent for the years ended December 31, 2016 and 2015, respectively. Effective January 1, 2017, the health care trend rate no longer has an impact on the PBOP expense on the Eversource Service PBOP Plan due to the benefit design changes effective with the 2016 plan amendment.

The following is a summary of the changes in plan assets and benefit obligations recognized in Regulatory Assets and OCI as well as amounts recognized in Regulatory Assets and OCI that were reclassified as net periodic benefit (expense)/income during the years presented:

<table><tr><td rowspan="3"></td><td colspan="4">Regulatory Assets</td><td colspan="3">OCI</td></tr><tr><td colspan="7">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2017</td><td>2016</td><td>2017</td><td>2016</td><td></td></tr><tr><td>Actuarial Losses/(Gains) Arising During the Year</td><td>$     44.8</td><td>$     32.4</td><td>$     2.6</td><td>$     2.6</td><td>$     2.6</td><td>$     2.6</td><td>$     2</td></tr></table>

The following is a summary of the remaining Regulatory Assets and Accumulated Other Comprehensive Loss amounts that have not been recognized as components of net periodic benefit expense as of December 31, 2017 and 2016, as well as the amounts that are expected to be recognized as components in 2018:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">Regulatory Assets as of December 31,</td><td rowspan="2">Expected 2018 Expense</td><td colspan="3">AOCL as of December 31,</td><td rowspan="2">Expected 2018 Expense</td></tr><tr><td>2017</td><td>2016</td><td></td><td>2017</td><td>2016</td><td></td></tr><tr><td>Actuarial Loss</td><td>$     211.6</td><td>$     175.4</td><td>$     8.8</td><td>$     6.6</td><td>$     4.5</td><td>$     0.3</td><td></td><td></td></tr><tr><td>Prior Service (Credit)/Cost</td><td>(221.2)</td><td>(239.5)</td><td>(21.7)</td><td>2.6</td><td>3.4</td><td>0.2</td><td></td><td></td></tr></table>

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>2018</td><td>2019</td><td>2020</td><td>2021</td><td>2022</td><td>2023 - 2027</td></tr><tr><td>Pension and SERP</td><td>$ 296.5</td><td>$ 304.7</td><td>$ 311.1</td><td>$ 320.8</td><td>$ 329.4</td><td>$ 1,739.7</td></tr><tr><td>PBOP</td><td>56.8</td><td>57.1</td><td>57.3</td><td>57.5</td><td>57.4</td><td>279.3</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 approximately $180 million in 2018, of which approximately $82 million and $6 million, will be contributed by CL&P and PSNH, respectively. The remaining $92 million is expected to be contributed by other Eversource subsidiaries, primarily Eversource Service. Eversource expects to make approximately $10 million in contributions to the PBOP Plan in 2018, of which approximately $5 million will be contributed by NSTAR Electric.



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, 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. For the year ended December 31, 2017, management has assumed long-term rates of return of 8.25 percent for the Eversource Pension and PBOP Plan assets. 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="4">2017</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>21.5%</td><td>8.5%</td><td>22.0%</td><td>8.5%</td></tr><tr><td>International</td><td>11.0%</td><td>8.5%</td><td>13.0%</td><td>8.5%</td></tr><tr><td>Emerging Markets</td><td>4.5%</td><td>10.0%</td><td>5.0%</td><td>10.0%</td></tr><tr><td>Private Equity</td><td>15.0%</td><td>12.0%</td><td>12.0%</td><td>12.0%</td></tr><tr><td>Debt Securities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Fixed Income</td><td>11.0%</td><td>4.0%</td><td>12.0%</td><td>4.5%</td></tr><tr><td>Public High Yield Fixed Income</td><td>4.0%</td><td>6.5%</td><td>3.0%</td><td>7.0%</td></tr><tr><td>Private Debt</td><td>15.0%</td><td>9.0%</td><td>10.0%</td><td>9.0%</td></tr><tr><td>Emerging Markets Debt</td><td>2.0%</td><td>6.5%</td><td>5.0%</td><td>7.5%</td></tr><tr><td>Real Estate and Other Assets</td><td>12.0%</td><td>7.5%</td><td>10.0%</td><td>7.5%</td></tr><tr><td>Hedge Funds</td><td>4.0%</td><td>6.0%</td><td>8.0%</td><td>7.0%</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 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="10">Fair Value Measurements as of December 31,</td></tr><tr><td colspan="5">2017</td><td colspan="5">2016</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></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></tr><tr><td>Equity Securities (1)</td><td>$ 535.4</td><td>$ —</td><td>$ 1,653.3</td><td>$ 2,188.7</td><td>$ 455.5</td><td>$ —</td><td>$ 1,279.7</td><td>$ 1,735.2</td><td></td><td></td></tr><tr><td>Private Equity</td><td>11.2</td><td>—</td><td>641.8</td><td>653.0</td><td>6.0</td><td>—</td><td>518.4</td><td>524.4</td><td></td><td></td></tr><tr><td>Fixed Income (2)</td><td>56.6</td><td>215.9</td><td>1,218.3</td><td>1,490.8</td><td>—</td><td>183.0</td><td>1,099.4</td><td>1,282.4</td><td></td><td></td></tr><tr><td>Real Estate and Other Assets</td><td>101.6</td><td>—</td><td>374.4</td><td>476.0</td><td>77.2</td><td>—</td><td>325.9</td><td>403.1</td><td></td><td></td></tr><tr><td>Hedge Funds</td><td>—</td><td>—</td><td>165.5</td><td>165.5</td><td>—</td><td>—</td><td>335.0</td><td>335.0</td><td></td><td></td></tr><tr><td>Total</td><td>$ 704.8</td><td>$ 215.9</td><td>$ 4,053.3</td><td>$ 4,974.0</td><td>$ 538.7</td><td>$ 183.0</td><td>$ 3,558.4</td><td>$ 4,280.1</td><td></td><td></td></tr><tr><td>Less: 401(h) PBOP Assets (3)</td><td></td><td></td><td></td><td>(234.5)</td><td></td><td></td><td></td><td></td><td>(204.1)</td><td></td></tr><tr><td>Total Pension Assets</td><td></td><td></td><td></td><td>$ 4,739.5</td><td></td><td></td><td></td><td>$ 4,076.0</td><td></td><td></td></tr></table>

PBOP Plan

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="10">Fair Value Measurements as of December 31,</td></tr><tr><td colspan="5">2017</td><td colspan="5">2016</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></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></tr><tr><td>Equity Securities (1)</td><td>$ 115.3</td><td>$ —</td><td>$ 241.9</td><td>$ 357.2</td><td>$ 88.6</td><td>$ —</td><td>$ 214.1</td><td>$ 302.7</td><td></td><td></td></tr><tr><td>Private Equity</td><td>—</td><td>—</td><td>31.3</td><td>31.3</td><td>—</td><td>—</td><td>32.2</td><td>32.2</td><td></td><td></td></tr><tr><td>Fixed Income (2)</td><td>23.4</td><td>44.0</td><td>133.9</td><td>201.3</td><td>9.5</td><td>44.8</td><td>132.3</td><td>186.6</td><td></td><td></td></tr><tr><td>Real Estate and Other Assets</td><td>22.4</td><td>—</td><td>29.0</td><td>51.4</td><td>15.5</td><td>—</td><td>27.5</td><td>43.0</td><td></td><td></td></tr><tr><td>Hedge Funds</td><td>—</td><td>—</td><td>46.5</td><td>46.5</td><td>—</td><td>—</td><td>47.2</td><td>47.2</td><td></td><td></td></tr><tr><td>Total</td><td>$ 161.1</td><td>$ 44.0</td><td>$ 482.6</td><td>$ 687.7</td><td>$ 113.6</td><td>$ 44.8</td><td>$ 453.3</td><td>$ 611.7</td><td></td><td></td></tr><tr><td>Add: 401(h) PBOP Assets (3)</td><td></td><td></td><td></td><td>234.5</td><td></td><td></td><td></td><td></td><td>204.1</td><td></td></tr><tr><td>Total PBOP Assets</td><td></td><td></td><td></td><td>$ 922.2</td><td></td><td></td><td></td><td>$ 815.8</td><td></td><td></td></tr></table>

 \( ^{(1)} \)  United States, International and Emerging Markets equity securities that are uncategorized include investments in commingled funds and hedge funds that are overlayed 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 fixed income strategies, and hedge funds that are overlayed with fixed income futures.

(3) 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, corporate bonds and high yield bond funds, 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 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. Hedge Funds are recorded at NAV based on the values of the underlying assets. Private Equity investments, Fixed Income partnership funds and Real Estate and Other 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. The Company has retrospectively adopted new accounting guidance that eliminates the requirement to classify assets valued at NAV, as a practical expedient, within the fair value hierarchy. Prior to the adoption of this guidance, these investments were classified as Level 2 or Level 3 in the fair value hierarchy. The adoption of this guidance changes fair value measurement disclosures, but does not impact the methodology for valuing the investments or financial statement results.

## B. Defined Contribution Plan

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. For newly hired employees, the Eversource 401k Plan provides employer matching contributions of 100 percent up to a maximum of three 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 defined 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>2017</td><td>$ 34.5</td><td>$ 4.6</td><td>$ 8.5</td><td>$ 3.7</td></tr><tr><td>2016</td><td>31.8</td><td>4.5</td><td>8.1</td><td>3.4</td></tr><tr><td>2015</td><td>30.4</td><td>4.8</td><td>7.3</td><td>3.4</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 8,000,000 new shares for various types of awards, including RSUs and performance shares, to eligible employees, officers, and board members. As of December 31, 2017 and 2016, Eversource had 2,445,110 and 2,692,350 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 APIC 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.

• Stock Options - All outstanding stock options were exercised during 2017.



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, 2016</td><td>724,270</td><td>47.86</td></tr><tr><td>Granted</td><td>299,285</td><td>55.97</td></tr><tr><td>Shares Issued</td><td>(289,635)</td><td>52.26</td></tr><tr><td>Forfeited</td><td>(16,881)</td><td>55.60</td></tr><tr><td>Outstanding as of December 31, 2017</td><td>717,039</td><td>49.29</td></tr></table>

The weighted average grant-date fair value of RSUs granted for the years ended December 31, 2017, 2016 and 2015 was $55.97, $54.67 and $54.57, respectively. As of December 31, 2017 and 2016, the number and weighted average grant-date fair value of unvested RSUs was 388,269 and $56.15 per share, and 322,158 and $53.47 per share, respectively. During 2017, there were 306,087 RSUs at a weighted average grant-date fair value of $52.75 per share that vested during the year and were either paid or deferred. As of December 31, 2017, 328,770 RSUs were fully vested and deferred and an additional 368,856 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, 2016</td><td>522,934</td><td>51.09</td></tr><tr><td>Granted</td><td>180,032</td><td>55.70</td></tr><tr><td>Shares Issued</td><td>(173,914)</td><td>43.48</td></tr><tr><td>Forfeited</td><td>(18,487)</td><td>47.06</td></tr><tr><td>Outstanding as of December 31, 2017</td><td>510,565</td><td>55.45</td></tr></table>

The weighted average grant-date fair value of performance shares granted for the years ended December 31, 2017, 2016 and 2015 was $55.70, $53.64 and $55.04, respectively. As of December 31, 2017 and 2016, the number and weighted average grant-date fair value of unvested performance shares was 331,207 and $55.79 per share, and 301,363 and $51.52 per share, respectively. During 2017, there were 131,308 performance shares at a weighted average grant-date fair value of $47.12 per share that vested during the year and were either paid or deferred. As of December 31, 2017, 179,358 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>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Compensation Expense</td><td>$ 19.7</td><td>$ 23.6</td><td>$ 23.1</td><td></td></tr><tr><td>Future Income Tax Benefit</td><td>8.0</td><td>9.6</td><td>9.4</td><td></td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="4">2017</td><td colspan="4">2016</td><td colspan="4">2015</td></tr><tr><td colspan="2">CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td colspan="2">NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td colspan="2"><img src="imgs/img_in_image_box_1504_2016_1604_2104.jpg" ></td><td>PSNH</td></tr><tr><td>(Millions of Dollars)</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>Compensation Expense</td><td>$ 7.0</td><td>$ 7.0</td><td>$ 3.2</td><td>$ 9.1</td><td>$ 8.2</td><td>$ 3.5</td><td>$ 9.3</td><td>$ 7.5</td><td>$ 3.2</td><td></td><td></td><td></td></tr><tr><td>Future Income Tax Benefit</td><td>2.9</td><td>2.8</td><td>1.3</td><td>3.7</td><td>3.3</td><td>1.4</td><td>3.8</td><td>3.1</td><td>1.3</td><td></td><td></td><td></td></tr></table>

As of December 31, 2017, there was $20.1 million of total unrecognized compensation expense related to nonvested share-based awards for Eversource, including $7.3 million for CL&P, $7.1 million for NSTAR Electric and $3.1 million for PSNH. This cost is expected to be recognized ratably over a weighted-average period of 1.83 years for Eversource and NSTAR Electric, 1.84 years for CL&P and 1.82 years for PSNH.

An income tax rate of 40 percent was used to estimate the tax effect on total share-based payments determined under the fair-value based method for all awards. The Company generally settles fully vested RSUs and performance shares with the issuance of common shares purchased in the open market.

In 2016, the Company adopted new accounting guidance, which prospectively changed the accounting for excess tax benefits associated with the distribution of stock compensation awards and also changed the presentation of excess tax benefits on the statement of cash flows from a financing activity to an operating activity. For the years ended December 31, 2017 and 2016, the impact of the ASU was to reduce income tax expense by $2.9 million and $19.1 million, respectively, which increased cash flows from operating activities on the statement of cash flows. For the year ended December 31, 2015, changes in excess tax benefits totaling $9.5 million increased cash flows from financing activities.



Stock Options: All remaining outstanding stock options under the NSTAR Incentive Plan were exercised during 2017. A summary of stock option transactions is as follows:

<table><tr><td></td><td>Options</td><td>Weighted Average Exercise Price</td><td>Intrinsic Value (Millions)</td></tr><tr><td>Outstanding and Exercisable - December 31, 2016</td><td>124,640</td><td>$ 25.84</td><td>$ 3.7</td></tr><tr><td>Exercised</td><td>(124,640)</td><td>$ 25.84</td><td>$ 4.4</td></tr><tr><td>Outstanding and Exercisable - December 31, 2017</td><td>—</td><td>$ —</td><td>$ —</td></tr></table>

Cash received for options exercised during the year ended December 31, 2017 totaled $3.2 million. The tax benefit realized from stock options exercised totaled $1.8 million for the year ended December 31, 2017.

## 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, which is included in Other Long-Term Liabilities on the balance sheets, as well as the related expense included in Operations and Maintenance Expense on the income statements, are as follows:

<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>2017</td><td>2016</td><td>2015</td></tr><tr><td>Actuarially-Determined Liability</td><td>$ 53.4</td><td>$ 54.2</td><td>$ 55.2</td></tr><tr><td>Other Retirement Benefits Expense</td><td>2.8</td><td>2.9</td><td>3.9</td></tr></table>

As of and For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="3">2017</td><td colspan="3">2016</td><td colspan="3">2015</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>Actuarially-Determined Liability</td><td>$ 0.3</td><td>$ 0.1</td><td>$ 1.9</td><td>$ 0.3</td><td>$ 0.1</td><td>$ 2.0</td><td>$ 0.4</td><td>$ 0.2</td><td>$ 2.4</td></tr><tr><td>Other Retirement Benefits Expense</td><td>1.0</td><td>1.0</td><td>0.5</td><td>1.1</td><td>0.9</td><td>0.6</td><td>1.5</td><td>1.3</td><td>0.7</td></tr></table>

## 10. INCOME TAXES

The components of income tax expense are 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>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Current Income Taxes:</td><td></td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>$ 58.9</td><td>$ 38.9</td><td>$ 6.2</td><td></td></tr><tr><td>State</td><td>31.6</td><td>53.0</td><td>45.7</td><td></td></tr><tr><td>Total Current</td><td>90.5</td><td>91.9</td><td>51.9</td><td></td></tr><tr><td>Deferred Income Taxes, Net:</td><td></td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>433.0</td><td>427.9</td><td>436.1</td><td></td></tr><tr><td>State</td><td>58.6</td><td>38.6</td><td>55.6</td><td></td></tr><tr><td>Total Deferred</td><td>491.6</td><td>466.5</td><td>491.7</td><td></td></tr><tr><td>Investment Tax Credits, Net</td><td>(3.2)</td><td>(3.4)</td><td>(3.6)</td><td></td></tr><tr><td>Income Tax Expense</td><td>$ 578.9</td><td>$ 555.0</td><td>$ 540.0</td><td></td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="3">2017</td><td colspan="3">2016</td><td colspan="3">2015</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>Current Income Taxes:</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>$ 50.9</td><td>$ 107.8</td><td>$ 18.6</td><td>$ 27.3</td><td>$ 86.4</td><td>$ (13.7)</td><td>$ 26.9</td><td>$ 32.8</td><td>$ (16.7)</td></tr><tr><td>State</td><td>17.4</td><td>25.6</td><td>6.2</td><td>13.3</td><td>39.5</td><td>8.8</td><td>15.8</td><td>21.4</td><td>6.0</td></tr><tr><td>Total Current</td><td>68.3</td><td>133.4</td><td>24.8</td><td>40.6</td><td>125.9</td><td>(4.9)</td><td>42.7</td><td>54.2</td><td>(10.7)</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></tr><tr><td>Federal</td><td>123.9</td><td>88.1</td><td>52.7</td><td>157.6</td><td>96.6</td><td>79.5</td><td>135.8</td><td>180.9</td><td>74.5</td></tr><tr><td>State</td><td>(4.6)</td><td>22.4</td><td>11.2</td><td>11.3</td><td>5.1</td><td>7.8</td><td>0.2</td><td>31.7</td><td>9.3</td></tr><tr><td>Total Deferred</td><td>119.3</td><td>110.5</td><td>63.9</td><td>168.9</td><td>101.7</td><td>87.3</td><td>136.0</td><td>212.6</td><td>83.8</td></tr><tr><td>Investment Tax Credits, Net</td><td>(1.0)</td><td>(1.8)</td><td>—</td><td>(1.2)</td><td>(1.8)</td><td>—</td><td>(1.3)</td><td>(1.8)</td><td>—</td></tr><tr><td>Income Tax Expense</td><td>$ 186.6</td><td>$ 242.1</td><td>$ 88.7</td><td>$ 208.3</td><td>$ 225.8</td><td>$ 82.4</td><td>$ 177.4</td><td>$ 265.0</td><td>$ 73.1</td></tr></table>



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

<table><tr><td rowspan="2">(Millions of Dollars, except percentages)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Income Before Income Tax Expense</td><td>$ 1,574.4</td><td>$ 1,504.8</td><td>$ 1,425.9</td><td></td></tr><tr><td>Statutory Federal Income Tax Expense at 35%</td><td>551.0</td><td>526.7</td><td>499.1</td><td></td></tr><tr><td>Tax Effect of Differences:</td><td></td><td></td><td></td><td></td></tr><tr><td>Depreciation</td><td>(10.8)</td><td>(3.4)</td><td>(4.6)</td><td></td></tr><tr><td>Investment Tax Credit Amortization</td><td>(3.2)</td><td>(3.4)</td><td>(3.6)</td><td></td></tr><tr><td>Other Federal Tax Credits</td><td>—</td><td>(3.5)</td><td>(3.8)</td><td></td></tr><tr><td>State Income Taxes, Net of Federal Impact</td><td>47.7</td><td>56.2</td><td>61.1</td><td></td></tr><tr><td>Dividends on ESOP</td><td>(8.4)</td><td>(8.4)</td><td>(8.1)</td><td></td></tr><tr><td>Tax Asset Valuation Allowance/Reserve Adjustments</td><td>7.0</td><td>3.3</td><td>4.7</td><td></td></tr><tr><td>Excess Stock Benefit (1)</td><td>(2.9)</td><td>(19.1)</td><td>—</td><td></td></tr><tr><td>Other, Net</td><td>(1.5)</td><td>6.6</td><td>(4.8)</td><td></td></tr><tr><td>Income Tax Expense</td><td>$ 578.9</td><td>$ 555.0</td><td>$ 540.0</td><td></td></tr><tr><td>Effective Tax Rate</td><td>36.8%</td><td>36.9%</td><td>37.9%</td><td></td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="3">(Millions of Dollars, except percentages)</td><td colspan="4">2017</td><td colspan="4">2016</td><td colspan="4">2015</td></tr><tr><td colspan="2">NSTAR</td><td colspan="2">NSTAR</td><td colspan="2">NSTAR</td><td rowspan="2">CL&amp;P</td><td colspan="2">NSTAR</td><td rowspan="2">Electric</td><td rowspan="2">PSNH</td><td></td></tr><tr><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>CL&amp;P</td><td>PSNH</td><td></td></tr><tr><td>Income Before Income Tax Expense</td><td>$ 563.4</td><td>$ 616.8</td><td>$ 224.7</td><td>$ 542.6</td><td>$ 576.6</td><td>$ 214.3</td><td>$ 476.8</td><td>$ 666.1</td><td>$ 187.5</td><td></td><td></td><td></td></tr><tr><td>Statutory Federal Income Tax Expense at 35%</td><td>197.2</td><td>215.9</td><td>78.6</td><td>189.9</td><td>201.8</td><td>75.0</td><td>166.9</td><td>233.1</td><td>65.6</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>(5.2)</td><td>(3.0)</td><td>1.1</td><td>1.6</td><td>(3.1)</td><td>1.0</td><td>(1.7)</td><td>(1.7)</td><td>0.5</td><td></td><td></td><td></td></tr><tr><td>Investment Tax Credit Amortization</td><td>(1.0)</td><td>(1.8)</td><td>—</td><td>(1.2)</td><td>(1.8)</td><td>—</td><td>(1.3)</td><td>(1.8)</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Other Federal Tax Credits</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>(3.5)</td><td>—</td><td>—</td><td>(3.8)</td><td></td><td></td><td></td></tr><tr><td>State Income Taxes, Net of Federal Impact</td><td>4.5</td><td>31.2</td><td>11.3</td><td>14.5</td><td>29.0</td><td>10.8</td><td>9.2</td><td>34.5</td><td>9.9</td><td></td><td></td><td></td></tr><tr><td>Tax Asset Valuation Allowance/Reserve Adjustments</td><td>(9.5)</td><td>—</td><td>—</td><td>1.5</td><td>—</td><td>—</td><td>1.2</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Excess Stock Benefit (1)</td><td>(0.7)</td><td>(0.7)</td><td>(0.3)</td><td>(0.9)</td><td>(1.2)</td><td>(0.4)</td><td>—</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Other, Net</td><td>1.3</td><td>0.5</td><td>(2.0)</td><td>2.9</td><td>1.1</td><td>(0.5)</td><td>3.1</td><td>0.9</td><td>0.9</td><td></td><td></td><td></td></tr><tr><td>Income Tax Expense</td><td>$ 186.6</td><td>$ 242.1</td><td>$ 88.7</td><td>$ 208.3</td><td>$ 225.8</td><td>$ 82.4</td><td>$ 177.4</td><td>$ 265.0</td><td>$ 73.1</td><td></td><td></td><td></td></tr><tr><td>Effective Tax Rate</td><td>33.1%</td><td>39.2%</td><td>39.5%</td><td>38.4%</td><td>39.2%</td><td>38.4%</td><td>37.2%</td><td>39.8%</td><td>39.0%</td><td></td><td></td><td></td></tr></table>

(1) In 2016, the Company adopted new accounting guidance, which prospectively changed the accounting for excess tax benefits associated with the distribution of stock compensation awards, previously recognized in Capital Surplus, Paid In within Common Shareholders' Equity on the balance sheet, to recognition within income tax expense in the income statement. See Note 1D, "Summary of Significant Accounting Policies - Accounting Standards," for further information.

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="2">Eversource (Millions of Dollars)</td><td colspan="3">As of December 31,</td></tr><tr><td>2017</td><td>2016</td><td></td></tr><tr><td>Deferred Tax Assets:</td><td></td><td></td><td></td></tr><tr><td>Employee Benefits</td><td>$ 442.1</td><td>$ 640.6</td><td></td></tr><tr><td>Derivative Liabilities</td><td>111.8</td><td>192.6</td><td></td></tr><tr><td>Regulatory Deferrals - Liabilities</td><td>205.6</td><td>290.9</td><td></td></tr><tr><td>Allowance for Uncollectible Accounts</td><td>50.1</td><td>76.6</td><td></td></tr><tr><td>Tax Effect - Tax Regulatory Liabilities</td><td>832.6</td><td>11.8</td><td></td></tr><tr><td>Federal Net Operating Loss Carryforwards</td><td>47.8</td><td>—</td><td></td></tr><tr><td>Purchase Accounting Adjustment</td><td>69.9</td><td>112.2</td><td></td></tr><tr><td>Other</td><td>149.5</td><td>170.5</td><td></td></tr><tr><td>Total Deferred Tax Assets</td><td>1,909.4</td><td>1,495.2</td><td></td></tr><tr><td>Less: Valuation Allowance</td><td>14.6</td><td>5.1</td><td></td></tr><tr><td>Net Deferred Tax Assets</td><td>$ 1,894.8</td><td>$ 1,490.1</td><td></td></tr><tr><td>Deferred Tax Liabilities:</td><td></td><td></td><td></td></tr><tr><td>Accelerated Depreciation and Other Plant-Related Differences</td><td>$ 3,562.0</td><td>$ 5,001.2</td><td></td></tr><tr><td>Property Tax Accruals</td><td>56.7</td><td>81.9</td><td></td></tr><tr><td>Regulatory Amounts:</td><td></td><td></td><td></td></tr><tr><td>Regulatory Deferrals - Assets</td><td>924.9</td><td>1,321.8</td><td></td></tr><tr><td>Tax Effect - Tax Regulatory Assets</td><td>243.1</td><td>252.6</td><td></td></tr><tr><td>Goodwill Regulatory Asset - 1999 Merger</td><td>99.8</td><td>186.7</td><td></td></tr><tr><td>Derivative Assets</td><td>17.4</td><td>29.5</td><td></td></tr><tr><td>Other</td><td>288.4</td><td>223.6</td><td></td></tr><tr><td>Total Deferred Tax Liabilities</td><td>$ 5,192.3</td><td>$ 7,097.3</td><td></td></tr></table>

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="6">As of December 31,</td></tr><tr><td colspan="3">2017</td><td colspan="3">2016</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>Deferred Tax Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Employee Benefits</td><td>$ 112.3</td><td>$ 34.0</td><td>$ 38.0</td><td>$ 138.8</td><td>$ 69.5</td><td>$ 46.5</td></tr><tr><td>Derivative Liabilities</td><td>110.5</td><td>0.3</td><td>—</td><td>191.5</td><td>1.1</td><td>—</td></tr><tr><td>Regulatory Deferrals - Liabilities</td><td>12.0</td><td>139.8</td><td>17.9</td><td>6.3</td><td>194.9</td><td>36.7</td></tr><tr><td>Allowance for Uncollectible Accounts</td><td>20.6</td><td>17.3</td><td>2.9</td><td>33.0</td><td>25.7</td><td>4.1</td></tr><tr><td>Tax Effect - Tax Regulatory Liabilities</td><td>337.2</td><td>281.2</td><td>116.8</td><td>4.9</td><td>3.3</td><td>2.6</td></tr><tr><td>Other</td><td>70.7</td><td>4.9</td><td>49.6</td><td>59.4</td><td>6.6</td><td>56.4</td></tr><tr><td>Total Deferred Tax Assets</td><td>663.3</td><td>477.5</td><td>225.2</td><td>433.9</td><td>301.1</td><td>146.3</td></tr><tr><td>Less: Valuation Allowance</td><td>6.3</td><td>—</td><td>—</td><td>4.5</td><td>—</td><td>—</td></tr><tr><td>Net Deferred Tax Assets</td><td>$ 657.0</td><td>$ 477.5</td><td>$ 225.2</td><td>$ 429.4</td><td>$ 301.1</td><td>$ 146.3</td></tr><tr><td>Deferred Tax Liabilities:</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>$ 1,224.9</td><td>$ 1,229.2</td><td>$ 502.5</td><td>$ 1,700.3</td><td>$ 1,901.9</td><td>$ 726.3</td></tr><tr><td>Property Tax Accruals</td><td>20.7</td><td>24.2</td><td>5.5</td><td>29.7</td><td>36.8</td><td>8.0</td></tr><tr><td>Regulatory Amounts:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Regulatory Deferrals - Assets</td><td>310.6</td><td>267.1</td><td>103.6</td><td>473.4</td><td>381.7</td><td>142.1</td></tr><tr><td>Tax Effect - Tax Regulatory Assets</td><td>173.1</td><td>9.8</td><td>11.4</td><td>170.4</td><td>44.8</td><td>12.2</td></tr><tr><td>Goodwill Regulatory Asset - 1999 Merger</td><td>—</td><td>85.7</td><td>—</td><td>—</td><td>160.3</td><td>—</td></tr><tr><td>Derivative Assets</td><td>17.4</td><td>—</td><td>—</td><td>27.0</td><td>—</td><td>—</td></tr><tr><td>Other</td><td>13.7</td><td>137.3</td><td>45.7</td><td>16.3</td><td>102.7</td><td>43.1</td></tr><tr><td>Total Deferred Tax Liabilities</td><td>$ 1,760.4</td><td>$ 1,753.3</td><td>$ 668.7</td><td>$ 2,417.1</td><td>$ 2,628.2</td><td>$ 931.7</td></tr></table>

2017 Federal Legislation: On December 22, 2017, the "Tax Cuts and Jobs Act" (the "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. In terms of the impacts to the regulated companies, the most significant changes will be (1) the benefit of incurring a lower federal income tax expense, which we expect to be passed back to customers, and (2) the provisional regulated excess ADIT liabilities that we expect to benefit customers in future periods, which were estimated to be approximately $2.9 billion (approximately $1.0



billion at CL&P, $1.1 billion at NSTAR Electric and $0.4 billion at PSNH) as of December 31, 2017 and recognized as regulatory liabilities on the balance sheet.

The Eversource regulated companies are currently working with their applicable state regulatory commissions, who have opened investigations to examine the impact of the Act on customer rates. FERC has yet to address how the Act would impact transmission rates. Eversource, CL&P, NSTAR Electric, and PSNH will continue to evaluate the impacts of the Act, which will vary depending on the ultimate amount and timing of when certain income tax benefits will benefit customers, and will vary by jurisdiction.

Although the impacts could not be finalized upon the issuance of this combined Annual Report on Form 10-K, reasonable provisional estimates were recognized as of December 31, 2017. In accordance with SEC Staff Accounting Bulletin No. 118 ("SAB 118"), additional re-measurement may occur based on final analysis, computations, technical corrections, or other forms of guidance issued from regulatory agencies or commissions. While the Company believes the impacts of the Act were appropriately accounted for in accordance with the applicable authoritative guidance, the ultimate outcome may be different from the provisional estimates recorded, and those differences may materially impact its future statement of financial position, results of operations, and cash flows.

Carryforwards: The following tables provide the amounts and expiration dates of state tax credit and loss carryforwards and federal tax credit and net operating loss carryforwards:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="6">As of December 31, 2017</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Expiration Range</td><td></td></tr><tr><td>Federal Net Operating Loss</td><td>$ 197.3</td><td>—</td><td>—</td><td>—</td><td>2027-2037</td><td></td></tr><tr><td>Federal Charitable Contribution</td><td>18.7</td><td>—</td><td>—</td><td>—</td><td>2017-2022</td><td></td></tr><tr><td>State Net Operating Loss</td><td>82.8</td><td>—</td><td>—</td><td>—</td><td>2028-2037</td><td></td></tr><tr><td>State Tax Credit</td><td>139.0</td><td>94.5</td><td>—</td><td>—</td><td>2017-2022</td><td></td></tr><tr><td>State Charitable Contribution</td><td>31.4</td><td>—</td><td>—</td><td>—</td><td>2017-2022</td><td></td></tr></table>

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="6">As of December 31, 2016</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>Expiration Range</td><td></td></tr><tr><td>Federal Tax Credit</td><td>8.6</td><td>—</td><td>—</td><td>—</td><td>—</td><td></td></tr><tr><td>Federal Charitable Contribution</td><td>27.8</td><td>—</td><td>—</td><td>—</td><td>2016 - 2019</td><td></td></tr><tr><td>State Tax Credit</td><td>111.1</td><td>80.5</td><td>—</td><td>—</td><td>2016 - 2021</td><td></td></tr><tr><td>State Charitable Contribution</td><td>36.5</td><td>—</td><td>—</td><td>—</td><td>2016 - 2020</td><td></td></tr></table>

In 2017, the company increased its valuation allowance reserve for state credits by $9.9 million ($1.8 million for CL&P), net of tax, to reflect and update for expired tax credits. In 2016, the Company increased its valuation allowance reserve for state credits by $1.3 million ($1.3 million for CL&P), net of tax, to reflect an update for expired tax credits.

For 2017 and 2016, state credit and state loss carryforwards have been partially reserved by a valuation allowance of $14.4 million and $4.5 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, 2015</td><td>$ 46.2</td><td>$ 14.3</td></tr><tr><td>Gross Increases - Current Year</td><td>9.9</td><td>2.6</td></tr><tr><td>Gross Increases - Prior Year</td><td>0.1</td><td>—</td></tr><tr><td>Lapse of Statute of Limitations</td><td>(8.2)</td><td>(3.4)</td></tr><tr><td>Balance as of December 31, 2015</td><td>48.0</td><td>13.5</td></tr><tr><td>Gross Increases - Current Year</td><td>9.9</td><td>3.9</td></tr><tr><td>Gross Increases - Prior Year</td><td>0.2</td><td>0.2</td></tr><tr><td>Lapse of Statute of Limitations</td><td>(9.7)</td><td>(2.3)</td></tr><tr><td>Balance as of December 31, 2016</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></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="2"></td><td colspan="3">Other Interest Expense/(Income)</td><td colspan="3">Accrued Interest Expense</td></tr><tr><td colspan="3">For the Years Ended December 31,</td><td colspan="3">As of December 31,</td></tr><tr><td>(Millions of Dollars)</td><td>2017</td><td>2016</td><td>2015</td><td>2017</td><td>2016</td><td></td></tr><tr><td>Eversource</td><td>$ —</td><td>$ —</td><td>(0.2)</td><td>$ 0.1</td><td>$ 1.8</td><td>$ 1.8</td></tr></table>

Tax Positions: During 2017 and 2016, 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, 2017:

<table><tr><td>Description</td><td>Tax Years</td></tr><tr><td>Federal</td><td>2017</td></tr><tr><td>Connecticut</td><td>2014 - 2017</td></tr><tr><td>Massachusetts</td><td>2014 - 2017</td></tr><tr><td>New Hampshire</td><td>2015 - 2017</td></tr></table>

Eversource estimates that during the next twelve months, differences of a non-timing nature could be resolved, resulting in a zero to $2.2 million decrease in unrecognized tax benefits by Eversource. These estimated changes are not expected to have a material impact on the earnings of Eversource. Other companies' impacts are not expected to be material.

## 11. COMMITMENTS AND CONTINGENCIES

## A. Environmental Matters

General: 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 related environmental matters. 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, 2016</td><td>$ 51.1</td><td>$ 4.6</td><td>$ 3.0</td><td>$ 4.5</td></tr><tr><td>Additions</td><td>20.6</td><td>0.6</td><td>1.8</td><td>1.2</td></tr><tr><td>Payments/Reductions</td><td>(5.9)</td><td>(0.3)</td><td>(1.0)</td><td>(0.4)</td></tr><tr><td>Balance as of December 31, 2016</td><td>65.8</td><td>4.9</td><td>3.8</td><td>5.3</td></tr><tr><td>Additions</td><td>6.2</td><td>0.5</td><td>1.8</td><td>1.0</td></tr><tr><td>Payments/Reductions</td><td>(17.1)</td><td>(0.7)</td><td>(2.9)</td><td>(0.6)</td></tr><tr><td>Balance as of December 31, 2017</td><td>$ 54.9</td><td>$ 4.7</td><td>$ 2.7</td><td>$ 5.7</td></tr></table>



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

<table><tr><td rowspan="2"></td><td colspan="3">As of December 31, 2017</td><td colspan="3">As of December 31, 2016</td></tr><tr><td>Number of Sites</td><td>Reserve (in millions)</td><td>Number of Sites</td><td>Reserve (in millions)</td><td></td><td></td></tr><tr><td>Eversource</td><td>59</td><td>$ 54.9</td><td>61</td><td>$ 65.8</td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>14</td><td>4.7</td><td>14</td><td>4.9</td><td></td><td></td></tr><tr><td>NSTAR Electric</td><td>15</td><td>2.7</td><td>17</td><td>3.8</td><td></td><td></td></tr><tr><td>PSNH</td><td>10</td><td>5.7</td><td>11</td><td>5.3</td><td></td><td></td></tr></table>

Included in the Eversource number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured 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 $49.0 million and $59.0 million as of December 31, 2017 and 2016, respectively, and related primarily to the natural gas business segment. The reduction in the reserve balance at the MGP sites was primarily due to a change in cost estimates at one site where actual contamination was less than originally estimated.

As of December 31, 2017, for 8 environmental sites (3 for CL&P, 1 for NSTAR Electric) 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, 2017, $25.4 million (including $1.8 million for CL&P and $0.3 million for NSTAR Electric) 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 $20 million ($1 million at CL&P) may be incurred in executing current remediation plans for these sites.

As of December 31, 2017, for 10 environmental sites (3 for CL&P) 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, 2017, $12.3 million (including $1.8 million for CL&P) had been accrued as a liability for these sites. As of December 31, 2017, for the remaining 41 environmental sites (including 8 for CL&P, 14 for NSTAR Electric and 10 for PSNH) that are included in the Company's reserve for environmental costs, the $17.2 million accrual (including $1.1 million for CL&P, $2.4 million for NSTAR Electric and $5.7 million for PSNH) represents management's best estimate of the probable liability and no additional loss is anticipated at this time.

CERCLA: Of the total environmental sites, nine sites (four for NSTAR Electric and three for PSNH) are superfund sites under the federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (CERCLA) and its amendments or state equivalents for which the Company has been notified that it is a potentially responsible party but for which the site assessment and remediation are not being managed by the Company. As of December 31, 2017, a liability of $0.9 million accrued on these sites represents management's best estimate of its potential remediation costs with respect to these superfund sites.

Environmental Rate Recovery: 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 recovers a certain level of environmental costs currently in rates. CL&P and NSTAR Electric do 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 long-term contractual arrangements as of December 31, 2017 are as follows:

<table><tr><td>Eversource
(Millions of Dollars)</td><td>2018</td><td>2019</td><td>2020</td><td>2021</td><td>2022</td><td>Thereafter</td><td>Total</td></tr><tr><td>Supply and Stranded Cost</td><td>$ 81.7</td><td>$ 69.3</td><td>$ 74.6</td><td>$ 68.8</td><td>$ 63.7</td><td>$ 144.3</td><td>$ 502.4</td></tr><tr><td>Renewable Energy</td><td>242.9</td><td>242.5</td><td>241.7</td><td>232.2</td><td>224.5</td><td>1,665.7</td><td>2,849.5</td></tr><tr><td>Peaker CfDs</td><td>26.1</td><td>24.2</td><td>34.0</td><td>32.3</td><td>23.4</td><td>53.3</td><td>193.3</td></tr><tr><td>Natural Gas Procurement</td><td>225.5</td><td>219.2</td><td>169.3</td><td>148.7</td><td>131.4</td><td>989.6</td><td>1,883.7</td></tr><tr><td>Transmission Support Commitments</td><td>22.8</td><td>23.0</td><td>23.2</td><td>15.2</td><td>16.5</td><td>16.5</td><td>117.2</td></tr><tr><td>Total</td><td>$ 599.0</td><td>$ 578.2</td><td>$ 542.8</td><td>$ 497.2</td><td>$ 459.5</td><td>$ 2,869.4</td><td>$ 5,546.1</td></tr><tr><td>CL&amp;P
(Millions of Dollars)</td><td>2018</td><td>2019</td><td>2020</td><td>2021</td><td>2022</td><td>Thereafter</td><td>Total</td></tr><tr><td>Supply and Stranded Cost</td><td>$ 58.7</td><td>$ 56.7</td><td>$ 69.5</td><td>$ 63.7</td><td>$ 59.1</td><td>$ 121.6</td><td>$ 429.3</td></tr><tr><td>Renewable Energy</td><td>84.1</td><td>85.4</td><td>85.5</td><td>85.8</td><td>86.6</td><td>655.5</td><td>1,082.9</td></tr><tr><td>Peaker CfDs</td><td>26.1</td><td>24.2</td><td>34.0</td><td>32.3</td><td>23.4</td><td>53.3</td><td>193.3</td></tr><tr><td>Transmission Support Commitments</td><td>9.0</td><td>9.1</td><td>9.2</td><td>6.0</td><td>6.5</td><td>6.5</td><td>46.3</td></tr><tr><td>Total</td><td>$ 177.9</td><td>$ 175.4</td><td>$ 198.2</td><td>$ 187.8</td><td>$ 175.6</td><td>$ 836.9</td><td>$ 1,751.8</td></tr></table>



<table><tr><td colspan="10">NSTAR Electric</td></tr><tr><td colspan="10">(Millions of Dollars)</td></tr><tr><td>Supply and Stranded Cost</td><td>2018</td><td>2019</td><td>2020</td><td>2021</td><td>2022</td><td>Thereafter</td><td>Total</td><td></td><td></td></tr><tr><td>Renewable Energy</td><td>$ 5.5</td><td>$ 5.5</td><td>$ 3.1</td><td>$ 3.1</td><td>$ 3.1</td><td>$ 22.0</td><td>$ 42.3</td><td></td><td></td></tr><tr><td>Transmission Support Commitments</td><td>96.1</td><td>94.3</td><td>92.6</td><td>88.2</td><td>88.4</td><td>489.4</td><td>949.0</td><td></td><td></td></tr><tr><td>Total</td><td>9.0</td><td>9.0</td><td>9.1</td><td>6.0</td><td>6.5</td><td>6.5</td><td>46.1</td><td></td><td></td></tr><tr><td></td><td>$ 110.6</td><td>$ 108.8</td><td>$ 104.8</td><td>$ 97.3</td><td>$ 98.0</td><td>$ 517.9</td><td>$ 1,037.4</td><td></td><td></td></tr><tr><td colspan="10">PSNH</td></tr><tr><td colspan="10">(Millions of Dollars)</td></tr><tr><td>Supply and Stranded Cost</td><td>2018</td><td>2019</td><td>2020</td><td>2021</td><td>2022</td><td>Thereafter</td><td>Total</td><td></td><td></td></tr><tr><td>Renewable Energy</td><td>$ 17.5</td><td>$ 7.1</td><td>$ 2.0</td><td>$ 2.0</td><td>$ 1.5</td><td>$ 0.7</td><td>$ 30.8</td><td></td><td></td></tr><tr><td>Transmission Support Commitments</td><td>62.7</td><td>62.8</td><td>63.6</td><td>58.2</td><td>49.5</td><td>520.8</td><td>817.6</td><td></td><td></td></tr><tr><td>Total</td><td>4.8</td><td>4.9</td><td>4.9</td><td>3.2</td><td>3.5</td><td>3.5</td><td>24.8</td><td></td><td></td></tr><tr><td></td><td>$ 85.0</td><td>$ 74.8</td><td>$ 70.5</td><td>$ 63.4</td><td>$ 54.5</td><td>$ 525.0</td><td>$ 873.2</td><td></td><td></td></tr></table>

Supply and Stranded Cost: CL&P, NSTAR Electric and PSNH have various IPP contracts or purchase obligations for electricity, including payment obligations resulting from the buydown of electricity purchase contracts. Such contracts extend through 2024 for CL&P, 2031 for NSTAR Electric and 2023 for PSNH.

In addition, CL&P, along with UI, has four capacity CfDs for a total of approximately 787 MW of capacity consisting of three 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 or NSTAR Electric's default service contracts, the amounts of which vary with customers' energy needs. The contractual obligations table also does not include PSNH's short-term power supply management.

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 2038 for CL&P, 2031 for NSTAR Electric and 2033 for PSNH.

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, for the purchase of renewable energy and related products that are contingent on the future construction of energy facilities.

Peaker CfDs: In 2008, CL&P entered into three CfDs with developers of peaking generation units approved by PURA (Peaker CfDs). These units have a total of approximately 500 MW of peaking capacity. As directed by PURA, CL&P and UI have entered into a sharing agreement, 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: In the normal course of business, 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. These contracts extend through 2032.

Coal, Wood and Other: PSNH has entered into various arrangements for the purchase of coal, wood and the transportation services for fuel supply for its electric generating assets. On January 10, 2018, Eversource and PSNH completed the sale of PSNH's thermal generation assets, at which time, remaining future contractual obligations were transferred to the buyer. See Note 12, "Assets Held for Sale," for further information.

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.

The total costs incurred under these agreements 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>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Supply and Stranded Cost</td><td>$ 103.9</td><td>$ 152.5</td><td>$ 147.6</td><td></td></tr><tr><td>Renewable Energy</td><td>235.5</td><td>210.9</td><td>144.3</td><td></td></tr><tr><td>Peaker CfDs</td><td>38.7</td><td>47.7</td><td>42.7</td><td></td></tr><tr><td>Natural Gas Procurement</td><td>377.0</td><td>323.9</td><td>428.6</td><td></td></tr><tr><td>Coal, Wood and Other</td><td>47.7</td><td>55.7</td><td>95.9</td><td></td></tr><tr><td>Transmission Support Commitments</td><td>19.8</td><td>15.9</td><td>25.3</td><td></td></tr></table>



For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="12">For the Years Ended December 31,</td></tr><tr><td colspan="3">2017</td><td colspan="3">2016</td><td colspan="3">2015</td><td colspan="3">2014</td></tr><tr><td>(Millions of Dollars)</td><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&lt;sup&gt;2&lt;/sup&gt;</td><td>NSTAR Electric</td><td>PSNH</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Supply and Stranded Cost</td><td>$ 81.0</td><td>$ 4.0</td><td>$ 18.9</td><td>$ 132.7</td><td>$ 0.7</td><td>$ 19.1</td><td>$ 120.3</td><td>$ 6.5</td><td>$ 20.8</td><td></td><td></td><td></td></tr><tr><td>Renewable Energy</td><td>51.0</td><td>123.7</td><td>60.8</td><td>42.1</td><td>101.1</td><td>67.7</td><td>20.0</td><td>87.1</td><td>37.2</td><td></td><td></td><td></td></tr><tr><td>Speaker CIDs</td><td>38.7</td><td>—</td><td>—</td><td>47.7</td><td>—</td><td>—</td><td>42.7</td><td>—</td><td>—</td><td></td><td></td><td></td></tr><tr><td>Coal, Wood and Other Transmission Support Commitments</td><td>—</td><td>—</td><td>47.7</td><td>—</td><td>—</td><td>55.7</td><td>—</td><td>—</td><td>95.9</td><td></td><td></td><td></td></tr><tr><td></td><td>7.8</td><td>7.8</td><td>4.2</td><td>6.3</td><td>6.2</td><td>3.4</td><td>10.0</td><td>9.9</td><td>5.4</td><td></td><td></td><td></td></tr></table>

## 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 facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies collect these costs through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. These companies in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies have collected or are currently collecting 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 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 had previously awarded the Yankee Companies damages for Phase 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 III Damages - In August 2013, the Yankee Companies each filed subsequent lawsuits against the DOE seeking recovery of actual damages incurred in the years 2009 through 2012 ("DOE Phase III"). On March 25, 2016, the court issued its decision and awarded CYAPC, YAEC and MYAPC damages of $32.6 million, $19.6 million and $24.6 million, respectively. In total, the Yankee Companies were awarded $76.8 million of the $77.9 million in damages sought in DOE Phase III. The decision became final on July 18, 2016, and the Yankee Companies received the awards from the DOE on October 14, 2016. The Yankee Companies received FERC approval of their proposed distribution of certain amounts of the awarded damages proceeds to member companies, including CL&P, NSTAR Electric and PSNH, which CYAPC and MYAPC made in December 2016. MYAPC also refunded $56.5 million from its spent nuclear fuel trust, a portion of which was also refunded to the Eversource utility subsidiaries. In total, Eversource received $26.1 million, of which CL&P, NSTAR Electric and PSNH received $13.6 million, $8.6 million and $3.9 million, respectively. These amounts have been refunded to the customers of the respective Eversource utility subsidiaries.

DOE Phase IV Damages - On May 22, 2017, each of the Yankee Companies filed subsequent lawsuits against the DOE in the Court of Federal Claims seeking monetary damages totaling approximately $100 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"). The DOE Phase IV trial is expected to begin in 2018.

## 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.

Eversource parent issued a guaranty on behalf of its subsidiary, NPT, under which, beginning at the time the Northern Pass Transmission line goes into commercial operation, Eversource parent will 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. Eversource parent has also entered into a guaranty on behalf of NPT under which Eversource parent will guarantee NPT's obligations under a facility with a financial institution pursuant to which NPT may request letters of credit in an aggregate amount of up to approximately $14 million.

Eversource parent has also guaranteed certain indemnification and other obligations as a result of the sales of former unregulated subsidiaries and the termination of an unregulated business, with maximum exposures either not specified or not material.

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 to external parties, as of December 31, 2017:

<table><tr><td>Company</td><td>Description</td><td>Maximum Exposure (in millions)</td><td>Expiration Dates</td></tr><tr><td>On behalf of subsidiaries:</td><td></td><td></td><td></td></tr><tr><td>Eversource Gas Transmission LLC</td><td>Access Northeast Project Capital Contributions Guaranty (1)</td><td>$ 185.1</td><td>2021</td></tr><tr><td>Various</td><td>Surety Bonds (2)</td><td>40.4</td><td>2018</td></tr><tr><td>Eversource Service and Rocky River Realty Company</td><td>Lease Payments for Vehicles and Real Estate</td><td>7.8</td><td>2019 - 2024</td></tr></table>



(1) Eversource parent issued a declining balance guaranty on behalf of its subsidiary, Eversource Gas Transmission LLC, to guarantee the payment of the subsidiary's capital contributions for its investment in the Access Northeast project. The guaranty decreases as capital contributions are made. The guaranty will expire upon the earlier of the full performance of the guaranteed obligations or December 31, 2021.

(2) 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.

Aquarion has a $0.9 million letter of credit relating to an insurance program, which expires on December 31, 2018 and includes annual automatic renewals. As of December 31, 2017, and 2016, there were no amounts outstanding under the letter of credit. Aquarion also guarantees surety bonds with a maximum exposure of $1.2 million related to ongoing operations with expiration dates ranging through 2018, the majority of which will be renewed or extended.

## E. FERC ROE Complaints

Four separate complaints have been 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, 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 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. The Court found that the FERC failed to make an explicit finding that the 11.14 percent base ROE was unjust and unreasonable, as required under Section 206 of the Federal Power Act, before it set a new base ROE. The Court also found that the FERC did not provide a rational connection between the record evidence and its decision to select the midpoint of the upper half of the zone of reasonableness for the new base ROE.

Hearings on the fourth complaint were held in December 2017 before the Administrative Law Judge ("ALJ"), who is expected to issue an initial decision in March 2018.

A summary of the four separate complaints and the base ROEs pertinent to those complaints are as follows:

<table><tr><td>Complaint</td><td>15-Month Time Period of Complaint (Beginning as of Complaint Filing Date)</td><td>Original Base ROE Authorized by FERC at Time of Complaint Filing Date (1)</td><td>Base ROE Subsequently Authorized by FERC for First Complaint Period and also Effective from October 16, 2014 through April 14, 2017 (1)</td><td>Reserve (Pre-Tax and Excluding Interest) as of December 31, 2017 (in millions)</td><td>FERC ALJ Recommendation of Base ROE on Second and Third Complaints (Issued March 22, 2016)</td></tr><tr><td>First</td><td>10/1/2011 - 12/31/2012</td><td>11.14%</td><td>10.57%</td><td>$—</td><td>N/A</td></tr><tr><td>Second</td><td>12/27/2012 - 3/26/2014</td><td>11.14%</td><td>N/A</td><td>39.1</td><td>9.59%</td></tr><tr><td>Third</td><td>7/31/2014 - 10/30/2015</td><td>11.14%</td><td>10.57%</td><td>—</td><td>10.90%</td></tr><tr><td>Fourth</td><td>4/29/2016 - 7/28/2017</td><td>10.57%</td><td>10.57%</td><td>—</td><td>N/A</td></tr></table>

(1) The ROE billed during the period October 1, 2011 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 an incentive cap at 11.74 percent for the first complaint period and also effective from the date of the FERC order on October 16, 2014. This FERC order was vacated on April 14, 2017.

(2) CL&P, NSTAR Electric and PSNH have refunded all amounts associated with the first complaint period, totaling $38.9 million (pre-tax and excluding interest) at Eversource (consisting of $22.4 million at CL&P, $13.7 million at NSTAR Electric and $2.8 million at PSNH), reflecting both the base ROE and incentive cap prescribed by the FERC order.

(3) The 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, 2017.

On June 5, 2017, the NETOs, including Eversource, submitted a filing to the FERC to reinstate the base ROE of 11.14 percent with an associated ROE incentive cap of 13.5 percent effective June 8, 2017, as these were the last ROEs lawfully in effect for transmission billing purposes prior to the FERC order vacated by the Court on April 14, 2017. On October 6, 2017, the FERC did not accept the NETOs filing, temporarily leaving in place the ROEs (10.57 percent base ROE with an 11.74 percent incentive cap ROE) set in the first complaint proceeding until the FERC addresses the Court's decision. On November 6, 2017, the NETOs submitted a request for rehearing of the FERC's October 6, 2017 Order rejecting the compliance filing.

On October 5, 2017, the NETOs filed a series of motions, requesting that the FERC dismiss the four complaint proceedings. Alternatively, if the FERC does not dismiss the proceedings, the NETOs requested that the FERC consolidate all four complaint proceedings for expeditious resolution and/or stay the trial in the fourth complaint proceeding and resolve it based on the standards set in the April 14, 2017 Court decision.

At this time, the Company cannot reasonably estimate a range of gain or loss for the complaint proceedings. No events in 2017 provided a reasonable basis for a change to the reserve balance of $39.1 million (pre-tax, excluding interest) for the second complaint period, and the Company has not changed its reserve or recognized ROEs for any of the complaint periods.



Management cannot at this time predict the ultimate effect of the Court decision or future FERC action on any of the complaint periods or the estimated impacts on the financial position, results of operations or cash flows of Eversource, CL&P, NSTAR Electric or PSNH.

The average impact of a 10 basis point change to the base ROE for each of the 15-month complaint periods would affect Eversource's after-tax earnings by approximately $3 million.

## 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, Harbor Electric Energy Company, a wholly-owned subsidiary of 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.

In 2017, as a result of the settlement, NSTAR Electric expensed $4.9 million (pre-tax) of previously incurred capitalized costs associated with engineering work performed on the existing cable that will no longer be used. In addition, 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 will result in the initial $17.5 million of construction costs on the new cable to be expensed as incurred. Of this amount, NSTAR Electric expensed $11.1 million (pre-tax) of costs incurred on the new cable in 2017. Construction of the new cable is expected to be completed in 2019.

## 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.

## 12. ASSETS HELD FOR SALE

In June 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement, under the terms of which PSNH agreed to divest its generation assets, subject to NHPUC approval. The NHPUC approval for this agreement, as well as NHPUC approval of the final divestiture plan and auction process, were received in the second half of 2016. In October 2017, PSNH entered into two Purchase and Sale Agreements ("Agreements") to sell its thermal and hydroelectric generation assets to private investors at purchase prices of $175 million and $83 million, respectively, subject to adjustments as set forth in the Agreements. The NHPUC approved the Agreements in late November 2017, at which time the Company classified these assets as held for sale.

On January 10, 2018, PSNH completed the sale of its thermal generation assets, pursuant to the Agreement dated October 11, 2017. In accordance with the Purchase and Sale 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, resulting in net proceeds of $134.1 million. As of December 31, 2017, the thermal generation assets classified as assets held for sale are stated at fair value less costs to sell. Deferred costs of $516.1 million were included in Regulatory Assets on the Eversource and PSNH Balance Sheets, and represent the difference between the carrying value and the fair value less costs to sell of the thermal generation assets as of December 31, 2017. The hydroelectric generation assets are targeted to be sold in the first quarter of 2018 at an amount above net carrying value, and are therefore stated at carrying value. As of December 31, 2017, the difference between the carrying value of the hydroelectric generation assets and the expected proceeds from the sale was approximately $25 million, which will be recognized as a reduction to the stranded costs upon completion of the sale.

Upon completion of the divestiture, full recovery of PSNH's generation assets and transaction-related costs are expected to occur through a combination of cash flows during the remaining operating period, sales proceeds, and recovery of stranded costs via the issuance of bonds that will be secured by a non-bypassable charge or through recoveries in future rates billed to PSNH's customers. On January 30, 2018, the NHPUC approved the issuance of rate reduction bonds up to $690 million to recover stranded costs, subject to an audit by the NHPUC Audit Staff. This order is subject to an appeal period of 30 days.

For the years ended December 31, 2017, 2016 and 2015, pre-tax income associated with the assets held for sale was $60.0 million, $65.3 million and $56.9 million, respectively.



As of December 31, 2017, PSNH's generation assets held for sale, which are included in current assets on the Eversource and PSNH balance sheets, and are part of the Electric Distribution reportable segment, were as follows (liabilities held for sale were $1.2 million as of December 31, 2017):

<table><tr><td colspan="2">(Millions of Dollars)</td></tr><tr><td>Thermal Gross Plant</td><td>$ 1,091.4</td></tr><tr><td>Hydroelectric Gross Plant</td><td>83.0</td></tr><tr><td>Accumulated Depreciation</td><td>(575.4)</td></tr><tr><td>Net Plant</td><td>599.0</td></tr><tr><td>Fuel and Inventory</td><td>87.7</td></tr><tr><td>Materials and Supplies</td><td>27.3</td></tr><tr><td>Emission Allowances</td><td>19.1</td></tr><tr><td>Other Assets</td><td>2.6</td></tr><tr><td>Deferred Costs from Generation Asset Sale</td><td>(516.1)</td></tr><tr><td>Total Generation Assets Held for Sale</td><td>$ 219.6</td></tr></table>

As of December 31, 2017, the difference between the carrying value of the generation assets and the amounts recognized as assets held for sale represented the deferred costs on the thermal generation asset sale and were calculated as follows:

<table><tr><td colspan="2">(Millions of Dollars)</td></tr><tr><td>Generation Assets to be Sold (Carrying Value)</td><td>$ 735.7</td></tr><tr><td>Less: Generation Assets Held for Sale:</td><td></td></tr><tr><td>Thermal Generation Assets (Fair Value less Cost to Sell)</td><td>(161.7)</td></tr><tr><td>Hydroelectric Generation (Carrying Value)</td><td>(57.9)</td></tr><tr><td>Generation Assets Held for Sale</td><td>(219.6)</td></tr><tr><td>Deferred Costs from Generation Asset Sale</td><td>$ 516.1</td></tr></table>

## 13. LEASES

Eversource, including CL&P, NSTAR Electric and PSNH, has entered into lease agreements, some of which are capital leases, for the use of data processing and office equipment, vehicles, service centers, land and office space. In addition, CL&P, NSTAR Electric and PSNH incur costs associated with leases entered into by other Eversource subsidiaries, which include Eversource Service and Rocky River Realty Company, and are included below in their respective operating lease rental expenses and future minimum rental payments. These intercompany lease amounts are eliminated on an Eversource consolidated basis. The provisions of the Eversource, CL&P, NSTAR Electric and PSNH lease agreements generally contain renewal options. Certain lease agreements contain payments impacted by the commercial paper rate plus a credit spread or the consumer price index.

Operating lease rental payments charged to expense are 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>2017</td><td>$ 10.5</td><td>$ 11.7</td><td>$ 11.3</td><td>$ 3.3</td></tr><tr><td>2016</td><td>12.1</td><td>12.5</td><td>11.4</td><td>2.9</td></tr><tr><td>2015</td><td>12.1</td><td>12.5</td><td>11.8</td><td>2.8</td></tr></table>

Future minimum rental payments, excluding executory costs, such as property taxes, state use taxes, insurance, and maintenance, under long-term noncancelable leases, as of December 31, 2017 are as follows:

<table><tr><td>Operating Leases (Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>2018</td><td>$ 13.2</td><td>$ 1.8</td><td>$ 7.9</td><td>$ 1.0</td></tr><tr><td>2019</td><td>11.4</td><td>1.5</td><td>6.9</td><td>1.0</td></tr><tr><td>2020</td><td>10.0</td><td>1.3</td><td>6.1</td><td>0.9</td></tr><tr><td>2021</td><td>8.9</td><td>1.1</td><td>5.5</td><td>0.8</td></tr><tr><td>2022</td><td>7.4</td><td>1.0</td><td>4.5</td><td>0.6</td></tr><tr><td>Thereafter</td><td>19.7</td><td>1.0</td><td>15.4</td><td>2.0</td></tr><tr><td>Future minimum lease payments</td><td>$ 70.6</td><td>$ 7.7</td><td>$ 46.3</td><td>$ 6.3</td></tr></table>



<table><tr><td colspan="6">Capital Leases(Millions of Dollars)</td></tr><tr><td></td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td></td></tr><tr><td>2018</td><td>$ 2.9</td><td>$ 2.0</td><td>$ 0.5</td><td>$ 0.1</td><td></td></tr><tr><td>2019</td><td>3.3</td><td>2.0</td><td>0.6</td><td>—</td><td></td></tr><tr><td>2020</td><td>3.3</td><td>2.0</td><td>0.5</td><td>—</td><td></td></tr><tr><td>2021</td><td>2.8</td><td>1.4</td><td>0.6</td><td>—</td><td></td></tr><tr><td>2022</td><td>1.3</td><td>—</td><td>0.6</td><td>—</td><td></td></tr><tr><td>Thereafter</td><td>2.5</td><td>—</td><td>2.5</td><td>—</td><td></td></tr><tr><td>Future minimum lease payments</td><td>16.1</td><td>7.4</td><td>5.3</td><td>0.1</td><td></td></tr><tr><td>Less amount representing interest</td><td>3.1</td><td>1.7</td><td>1.2</td><td>—</td><td></td></tr><tr><td>Present value of future minimum lease payments</td><td>$ 13.0</td><td>$ 5.7</td><td>$ 4.1</td><td>$ 0.1</td><td></td></tr></table>

CL&P 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 included in the tables above. However, such contracts have been included in the contractual obligations table in Note 11B, "Commitments and Contingencies - Long-Term Contractual Arrangements," to the financial statements.

## 14. 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 and Long-Term Debt: The fair value of CI & 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 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 tables 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"></td><td colspan="6">As of December 31,</td></tr><tr><td colspan="3">2017</td><td colspan="3">2016</td></tr><tr><td>Eversource (Millions of Dollars)</td><td>Carrying Amount</td><td>Fair Value</td><td>Carrying Amount</td><td>Fair Value</td><td>Carrying Amount</td><td>Fair Value</td></tr><tr><td>Preferred Stock Not Subject to Mandatory Redemption</td><td>$ 155.6</td><td>$ 160.8</td><td>$ 155.6</td><td>$ 158.3</td><td></td><td></td></tr><tr><td>Long-Term Debt</td><td>12,325.5</td><td>12,877.1</td><td>9,603.2</td><td>9,980.5</td><td></td><td></td></tr><tr><td></td><td colspan="3">CL&amp;P</td><td colspan="3">NSTAR Electric</td></tr><tr><td></td><td>Carrying Amount</td><td>Fair Value</td><td>Carrying Amount</td><td>Fair Value</td><td>Carrying Amount</td><td>Fair Value</td></tr><tr><td>(Millions of Dollars)</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>As of December 31, 2017:</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>$ 116.2</td><td>$ 116.5</td><td>$ 43.0</td><td>$ 44.3</td><td>$ —</td><td>$ —</td></tr><tr><td>Long-Term Debt</td><td>3,059.1</td><td>3,430.5</td><td>2,943.8</td><td>3,156.5</td><td>1,002.4</td><td>1,038.2</td></tr><tr><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>As of December 31, 2016:</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>$ 116.2</td><td>$ 114.7</td><td>$ 43.0</td><td>$ 43.6</td><td>$ —</td><td>$ —</td></tr><tr><td>Long-Term Debt</td><td>2,766.0</td><td>3,049.6</td><td>2,644.6</td><td>2,790.6</td><td>1,072.0</td><td>1,109.7</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 11, "Summary of Significant Accounting Policies – Fair Value Measurements," for the fair value measurement policy and the fair value hierarchy.

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

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

<table><tr><td rowspan="2"></td><td colspan="6">For the Year Ended December 31, 2017</td><td colspan="6">For the Year Ended December 31, 2016</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 Gains/(Losses) on Marketable Securities</td><td>Defined Benefit Plans</td><td>Total</td><td>Qualified Cash Flow Hedging Instruments</td><td>Unrealized Gains/(Losses) on Marketable Securities</td><td>Defined Benefit Plans</td><td>Total</td></tr><tr><td>Balance as of January 1st</td><td>$ (8.2)</td><td>$ 0.4</td><td>$ (57.5)</td><td>$ (65.3)</td><td>$ (10.3)</td><td>$ (1.9)</td><td>$ (54.6)</td><td>$ (66.8)</td><td></td><td></td><td></td><td></td></tr><tr><td>OCI Before Reclassifications</td><td>—</td><td>(0.4)</td><td>(7.2)</td><td>(7.6)</td><td>—</td><td>2.3</td><td>(6.8)</td><td>(4.5)</td><td></td><td></td><td></td><td></td></tr><tr><td>Amounts Reclassified from AOCL</td><td>2.0</td><td>—</td><td>4.5</td><td>6.5</td><td>2.1</td><td>—</td><td>3.9</td><td>6.0</td><td></td><td></td><td></td><td></td></tr><tr><td>Net OCI</td><td>2.0</td><td>(0.4)</td><td>(2.7)</td><td>(1.1)</td><td>2.1</td><td>2.3</td><td>(2.9)</td><td>1.5</td><td></td><td></td><td></td><td></td></tr><tr><td>Balance as of December 31st</td><td>$ (6.2)</td><td>$ —</td><td>$ (60.2)</td><td>$ (66.4)</td><td>$ (8.2)</td><td>$ 0.4</td><td>$ (57.5)</td><td>$ (65.3)</td><td></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 AOCL 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 AOCL 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 and prior service costs that arose during the year and were recognized in AOCL. The related tax effects recognized in AOCL were net deferred tax assets of $4.1 million and $4.0 million in 2017 and 2016, respectively, and were net deferred tax liabilities of $2.0 million in 2015. The unamortized actuarial gains and losses and prior service costs on the defined benefit plans are amortized from AOCL into Operations and Maintenance expense over the average future employee service period, and are reflected in amounts reclassified from AOCL.

The following table sets forth the amounts reclassified from AOCL 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 AOCL</td><td rowspan="3">Statements of Income Line Item Impacted</td></tr><tr><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Qualified Cash Flow Hedging Instruments</td><td>$ (3.3)</td><td>$ (3.5)</td><td>$ (3.5)</td><td>Interest Expense</td><td></td></tr><tr><td>Tax Effect</td><td>1.3</td><td>1.4</td><td>1.4</td><td>Income Tax Expense</td><td></td></tr><tr><td>Qualified Cash Flow Hedging Instruments, Net of Tax</td><td>$ (2.0)</td><td>$ (2.1)</td><td>$ (2.1)</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>$ (6.2)</td><td>$ (5.6)</td><td>$ (6.6)</td><td>Operations and Maintenance Expense (1)</td><td></td></tr><tr><td>Amortization of Prior Service Cost</td><td>(1.1)</td><td>(0.8)</td><td>(0.2)</td><td>Operations and Maintenance Expense (1)</td><td></td></tr><tr><td>Total Defined Benefit Plan Costs</td><td>(7.3)</td><td>(6.4)</td><td>(6.8)</td><td></td><td></td></tr><tr><td>Tax Effect</td><td>2.8</td><td>2.5</td><td>2.6</td><td>Income Tax Expense</td><td></td></tr><tr><td>Defined Benefit Plan Costs, Net of Tax</td><td>$ (4.5)</td><td>$ (3.9)</td><td>$ (4.2)</td><td></td><td></td></tr><tr><td>Total Amounts Reclassified from AOCL, Net of Tax</td><td>$ (6.5)</td><td>$ (6.0)</td><td>$ (6.3)</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 9A, "Employee Benefits – Pension Benefits and Postretirement Benefits Other Than Pensions," for further information.

As of December 31, 2017, it is estimated that a pre-tax amount of $2.8 million (including $0.1 million for CL&P, $0.7 million for NSTAR Electric and $1.9 million for PSNH) will be reclassified from AOCL 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 $6.6 million will be reclassified from AOCL as a decrease to Net Income over the next 12 months as a result of the amortization of Pension, SERP and PBOP costs.

## 16. 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, Yankee Gas and NSTAR Gas, 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, 2017, all companies were in compliance with such covenant. Eversource, CL&P, NSTAR Electric, PSNH, Yankee Gas and NSTAR Gas were in compliance with all such provisions of the revolving credit agreements that may restrict the payment of dividends as of December 31, 2017.

The Retained Earnings balances subject to dividend restrictions were $3.6 billion for Eversource, $1.4 billion for CL&P, $1.9 billion for NSTAR Electric and $511.4 million for PSNH as of December 31, 2017. PSNH is further required to reserve an additional amount under its FERC hydroelectric license conditions. As of December 31, 2017, $14.3 million of PSNH's Retained Earnings was subject to restriction under its FERC hydroelectric license conditions and PSNH was in compliance with this provision.

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 Yankee Gas and NSTAR Gas. Such state law restrictions do not restrict the payment of dividends from retained earnings or net income.



## 17. 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, 2017 and 2016</td><td colspan="2">Issued as of December 31,</td></tr><tr><td>Par Value</td><td>2016</td><td>2017</td><td>2016</td><td></td></tr><tr><td>Eversource</td><td>$ 5</td><td>380,000,000</td><td>333,878,402</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>

On December 31, 2017, as a result of the WMECO merger with and into NSTAR Electric, WMECO's common stock was converted into 100 shares of NSTAR Electric common stock. In accordance with accounting guidance on combinations between entities under common control, NSTAR Electric's common stock has been retrospectively adjusted as if the merger occurred on January 1, 2015.

As of both December 31, 2017 and 2016, there were 16,992,594 Eversource common shares held as treasury shares. As of both December 31, 2017 and 2016, Eversource common shares outstanding were 316,885,808.

In 2016, the Company converted 321,228 Eversource common shares at a share price of $52.56 to Treasury Stock on the consolidated balance sheet at their weighted average original average cost of $24.26 per share.

## 18. 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 Board 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"></td><td rowspan="2">Redemption Price Per Share</td><td colspan="2">Shares Outstanding as of December 31,</td><td colspan="2">As of December 31,</td></tr><tr><td>2017</td><td>2016</td><td>2017</td><td>2016</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>$ 8.2</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>$</td><td>51.44</td><td>200,000</td><td>200,000</td><td>10.0</td></tr><tr><td>Total CL&amp;P</td><td></td><td></td><td></td><td>2,324,000</td><td>2,324,000</td><td>$ 116.2</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>43.0</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>$</td><td>100.00</td><td>23</td><td>—</td><td>—</td></tr><tr><td>Total Eversource - Preferred Stock of Subsidiaries</td><td></td><td></td><td></td><td></td><td>$ 155.6</td><td>$ 155.6</td></tr></table>



## 19. 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, 2017, 2016 and 2015. 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, 2017 and 2016. On the Eversource balance sheets, Common Shareholders' Equity was fully attributable to the parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.

For the years ended December 31, 2017, 2016 and 2015, there was no change in ownership of the common equity of CL&P and NSTAR Electric.

## 20. EARNINGS PER SHARE

Basic EPS is computed based upon the weighted average number of common shares outstanding during each period. Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards as if they were converted into common shares. The dilutive effect of unvested RSU and performance share awards 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. For the years ended December 31, 2017 and 2016, there were no antidilutive share awards excluded from the diluted EPS computation. For the year ended December 31, 2015, there were 1,474 antidilutive share awards excluded from the computation of diluted EPS.

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>2017</td><td>2016</td><td>2015</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 988.0</td><td>$ 942.3</td><td>$ 878.5</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>317,411,097</td><td>317,650,180</td><td>317,336,881</td><td></td></tr><tr><td>Dilutive Effect</td><td>620,483</td><td>804,059</td><td>1,095,806</td><td></td></tr><tr><td>Diluted</td><td>318,031,580</td><td>318,454,239</td><td>318,432,687</td><td></td></tr><tr><td>Basic EPS</td><td>$ 3.11</td><td>$ 2.97</td><td>$ 2.77</td><td></td></tr><tr><td>Diluted EPS</td><td>$ 3.11</td><td>$ 2.96</td><td>$ 2.76</td><td></td></tr></table>

## 21. SEGMENT INFORMATION

Presentation: Eversource is organized among the Electric Distribution, Electric Transmission and Natural Gas Distribution reportable segments and Other based on a combination of factors, including the characteristics of each segment's 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 and natural gas 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 and NSTAR Electric's solar power facilities. 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. On December 4, 2017, Eversource acquired Aquarion, which was considered to be a new operating segment, water. Financial statement results, however, were not considered material as a result of a short period of ownership by Eversource, and were not reported separately. Therefore, the results of the water operating segment have been included in Other for the year ended December 31, 2017.

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 CYCAP and YAEC, 4) the results of Aquarion's water business from the date of the acquisition on December 4, 2017 through December 31, 2017; and 5) the results of other unregulated subsidiaries, which are not part of its core business. In addition, Other in the tables below includes Eversource parent's equity ownership interests in certain natural gas pipeline projects owned by Enbridge, Inc., the Bay State Wind project, a renewable energy investment fund, and two companies that transmit hydroelectricity imported from the Hydro-Quebec system in Canada. In the ordinary course of business, Yankee Gas and NSTAR Gas purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline projects described above. These affiliate transaction costs total approximately $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.

The Electric Transmission segment includes a reduction to Operations and Maintenance expense of $27.5 million in 2016 for costs incurred in previous years that was recovered in transmission rates over the period June 1, 2016 through May 31, 2017. These costs were associated with the merger of Northeast Utilities and NSTAR.

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 expense.



## Eversource's segment information is as follows:

For the Year Ended December 31, 2017

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="7">Electric</td></tr><tr><td>Electric Distribution</td><td>Natural Gas Distribution</td><td>Electric Transmission</td><td>Other</td><td>Eliminations</td><td>Total</td><td></td></tr><tr><td>Operating Revenues</td><td>$ 5,542.9</td><td>$ 947.3</td><td>$ 1,301.7</td><td>$ 946.9</td><td>$ (986.8)</td><td>$ 7,752.0</td><td></td></tr><tr><td>Depreciation and Amortization</td><td>(542.6)</td><td>(72.9)</td><td>(209.4)</td><td>(41.1)</td><td>2.2</td><td>(863.8)</td><td></td></tr><tr><td>Other Operating Expenses</td><td>(4,046.0)</td><td>(713.5)</td><td>(382.6)</td><td>(814.6)</td><td>986.7</td><td>(4,970.0)</td><td></td></tr><tr><td>Operating Income</td><td>954.3</td><td>160.9</td><td>709.7</td><td>91.2</td><td>2.1</td><td>1,918.2</td><td></td></tr><tr><td>Interest Expense</td><td>(186.3)</td><td>(43.1)</td><td>(115.1)</td><td>(93.1)</td><td>15.8</td><td>(421.8)</td><td></td></tr><tr><td>Interest Income</td><td>7.3</td><td>0.1</td><td>1.8</td><td>15.8</td><td>(16.7)</td><td>8.3</td><td></td></tr><tr><td>Other Income, Net</td><td>15.0</td><td>0.9</td><td>27.1</td><td>1,112.7</td><td>(1,086.0)</td><td>69.7</td><td></td></tr><tr><td>Income Tax Expense</td><td>(288.3)</td><td>(44.2)</td><td>(228.7)</td><td>(17.6)</td><td>(0.1)</td><td>(578.9)</td><td></td></tr><tr><td>Net Income</td><td>502.0</td><td>74.6</td><td>394.8</td><td>1,109.0</td><td>(1,084.9)</td><td>995.5</td><td></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>(7.5)</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 497.4</td><td>$ 74.6</td><td>$ 391.9</td><td>$ 1,109.0</td><td>$ (1,084.9)</td><td>$ 988.0</td><td></td></tr><tr><td>Total Assets (as of)</td><td>$ 19,250.4</td><td>$ 3,595.2</td><td>$ 9,401.2</td><td>$ 18,403.8</td><td>$ (14,430.2)</td><td>$ 36,220.4</td><td></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>$ 161.6</td><td>$ —</td><td>$ 2,348.1</td><td></td></tr></table>

For the Year Ended December 31, 2016

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="7">Electric</td></tr><tr><td>Electric Distribution</td><td>Natural Gas Distribution</td><td>Electric Transmission</td><td>Other</td><td>Eliminations</td><td>Total</td><td></td></tr><tr><td>Operating Revenues</td><td>$ 5,594.3</td><td>$ 857.7</td><td>$ 1,210.0</td><td>$ 870.4</td><td>$ (893.3)</td><td>$ 7,639.1</td><td></td></tr><tr><td>Depreciation and Amortization</td><td>(504.7)</td><td>(65.3)</td><td>(185.8)</td><td>(33.5)</td><td>2.2</td><td>(787.1)</td><td></td></tr><tr><td>Other Operating Expenses</td><td>(4,155.1)</td><td>(628.9)</td><td>(321.8)</td><td>(778.1)</td><td>891.8</td><td>(4,992.1)</td><td></td></tr><tr><td>Operating Income</td><td>934.5</td><td>163.5</td><td>702.4</td><td>58.8</td><td>0.7</td><td>1,859.9</td><td></td></tr><tr><td>Interest Expense</td><td>(193.1)</td><td>(41.3)</td><td>(110.0)</td><td>(63.5)</td><td>6.9</td><td>(401.0)</td><td></td></tr><tr><td>Interest Income</td><td>10.0</td><td>0.1</td><td>1.2</td><td>7.0</td><td>(7.3)</td><td>11.0</td><td></td></tr><tr><td>Other Income, Net</td><td>4.8</td><td>0.6</td><td>18.3</td><td>1,020.1</td><td>(1,008.9)</td><td>34.9</td><td></td></tr><tr><td>Income Tax (Expense)/Benefit</td><td>(288.8)</td><td>(45.2)</td><td>(238.2)</td><td>16.5</td><td>0.7</td><td>(555.0)</td><td></td></tr><tr><td>Net Income</td><td>467.4</td><td>77.7</td><td>373.7</td><td>1,038.9</td><td>(1,007.9)</td><td>949.8</td><td></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>(7.5)</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 462.8</td><td>$ 77.7</td><td>$ 370.8</td><td>$ 1,038.9</td><td>$ (1,007.9)</td><td>$ 942.3</td><td></td></tr><tr><td>Total Assets (as of)</td><td>$ 18,367.5</td><td>$ 3,303.8</td><td>$ 8,751.5</td><td>$ 14,493.1</td><td>$ (12,862.7)</td><td>$ 32,053.2</td><td></td></tr><tr><td>Cash Flows Used for Investments in Plant</td><td>$ 812.6</td><td>$ 255.3</td><td>$ 801.0</td><td>$ 108.0</td><td>$ —</td><td>$ 1,976.9</td><td></td></tr></table>

For the Year Ended December 31, 2015

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="7">Electric</td></tr><tr><td>Electric Distribution</td><td>Natural Gas Distribution</td><td>Electric Transmission</td><td>Other</td><td>Eliminations</td><td>Total</td><td></td></tr><tr><td>Operating Revenues</td><td>$ 5,903.6</td><td>$ 995.5</td><td>$ 1,069.1</td><td>$ 863.6</td><td>$ (877.0)</td><td>$ 7,954.8</td><td></td></tr><tr><td>Depreciation and Amortization</td><td>(425.2)</td><td>(70.5)</td><td>(165.6)</td><td>(29.0)</td><td>2.1</td><td>(688.2)</td><td></td></tr><tr><td>Other Operating Expenses</td><td>(4,470.2)</td><td>(776.7)</td><td>(314.9)</td><td>(817.9)</td><td>877.3</td><td>(5,502.4)</td><td></td></tr><tr><td>Operating Income</td><td>1,008.2</td><td>148.3</td><td>588.6</td><td>16.7</td><td>2.4</td><td>1,764.2</td><td></td></tr><tr><td>Interest Expense</td><td>(186.3)</td><td>(36.9)</td><td>(105.8)</td><td>(48.0)</td><td>4.6</td><td>(372.4)</td><td></td></tr><tr><td>Interest Income</td><td>5.7</td><td>0.1</td><td>1.6</td><td>4.4</td><td>(5.1)</td><td>6.7</td><td></td></tr><tr><td>Other Income, Net</td><td>7.2</td><td>0.8</td><td>14.5</td><td>977.8</td><td>(972.8)</td><td>27.5</td><td></td></tr><tr><td>Income Tax (Expense)/Benefit</td><td>(322.8)</td><td>(40.1)</td><td>(191.6)</td><td>14.5</td><td>—</td><td>(540.0)</td><td></td></tr><tr><td>Net Income</td><td>512.0</td><td>72.2</td><td>307.3</td><td>965.4</td><td>(970.9)</td><td>886.0</td><td></td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>(4.7)</td><td>—</td><td>(2.8)</td><td>—</td><td>—</td><td>(7.5)</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 507.3</td><td>$ 72.2</td><td>$ 304.5</td><td>$ 965.4</td><td>$ (970.9)</td><td>$ 878.5</td><td></td></tr><tr><td>Cash Flows Used for Investments in Plant</td><td>$ 718.9</td><td>$ 182.2</td><td>$ 749.1</td><td>$ 73.9</td><td>$ —</td><td>$ 1,724.1</td><td></td></tr></table>



## 22. ACQUISITION OF AQUARION AND GOODWILL

## A. Acquisition of Aquarion

On December 4, 2017, Eversource acquired Aquarion from Macquarie Infrastructure Partners for $1.675 billion, consisting of approximately $880 million in cash purchase price and $795 million of assumed Aquarion debt. Aquarion is a holding company primarily engaged, through its three separate regulated water utility subsidiaries, in the water collection, treatment and distribution business, and operates 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. With the acquisition of Aquarion, Eversource is now the only U.S.-based electric utility to also own a water utility. The transaction was approved by PURA, the DPU, the NHPUC, the Maine PUC, and the Federal Communications Commission. Aquarion and its subsidiaries became wholly-owned subsidiaries of Eversource, and Eversource's consolidated financial information includes Aquarion and its subsidiaries' activity from December 4, 2017 through December 31, 2017.

The approximate $880 million cash purchase price includes the $745 million equity purchase price and a $135 million shareholder loan, paid at closing.

Purchase Price Allocation: The allocation of the total purchase price to the estimated fair values of the assets acquired and liabilities assumed has been determined based on the accounting guidance for fair value measurements, which defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The allocation of the total purchase price includes adjustments to record the fair value of unregulated and regulated long-term debt, non-utility land and buildings, regulatory assets not earning a return, and Aquarion's Homeowners Safety Valve unregulated business.

The fair values of Aquarion's assets and liabilities were determined based on significant estimates and assumptions, including Level 3 inputs, that are judgmental in nature. These estimates and assumptions include the timing and amounts of projected future cash flows and discount rates reflecting risk inherent in future cash flows. The excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed was recognized as goodwill.

The preliminary allocation of the cash purchase price is as follows:

<table><tr><td colspan="2">(Millions of Dollars)</td></tr><tr><td>Current Assets</td><td>$ 41.2</td></tr><tr><td>PP&amp;E</td><td>1,034.9</td></tr><tr><td>Goodwill</td><td>907.9</td></tr><tr><td>Other Noncurrent Assets, excluding Goodwill</td><td>207.6</td></tr><tr><td>Current Liabilities</td><td>(121.1)</td></tr><tr><td>Noncurrent Liabilities</td><td>(421.6)</td></tr><tr><td>Long-Term Debt</td><td>(771.2)</td></tr><tr><td>Total Cash Purchase Price</td><td>$ 877.7</td></tr></table>

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, 2016. 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 rowspan="2">(Pro forma amounts in millions, except share amounts)</td><td colspan="2">For the Years Ended December 31,</td></tr><tr><td>2017</td><td>2016</td></tr><tr><td>Operating Revenues</td><td>$ 7,947.7</td><td>$ 7,849.0</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>1,019.1</td><td>969.3</td></tr><tr><td>Basic EPS</td><td>3.21</td><td>3.05</td></tr><tr><td>Diluted EPS</td><td>3.20</td><td>3.04</td></tr></table>

Aquarion Revenues and Pre-Tax Income: The impact of Aquarion on Eversource's accompanying consolidated statement of income includes 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 completed the acquisition of Aquarion on December 4, 2017, resulting in the addition of $0.9 billion of goodwill. Upon completion of the acquisition, Eversource determined that the reporting units for the purpose of testing goodwill are Electric Distribution, Electric Transmission, Natural Gas Distribution and Water. The goodwill resulting from the Aquarion acquisition has been entirely allocated to the Water reporting unit. These reporting units are consistent with the operating segments underlying the reportable segments identified in Note 21, "Segment Information," to the financial statements.



Eversource completed its annual goodwill impairment test for Electric Distribution, Electric Transmission and Natural Gas Distribution reporting units as of October 1, 2017 and determined that no impairment existed. There were no events subsequent to October 1, 2017 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:

<table><tr><td>(Billions of Dollars)</td><td>Electric Distribution</td><td>Electric Transmission</td><td>Natural Gas Distribution</td><td>Parent and Other</td><td>Total</td></tr><tr><td>Balance as of January 1, 2017</td><td>$ 2.5</td><td>$ 0.6</td><td>$ 0.4</td><td>$ —</td><td>$ 3.5</td></tr><tr><td>Acquisition of Aquarion</td><td>—</td><td>—</td><td>—</td><td>0.9</td><td>0.9</td></tr><tr><td>Balance as of December 31, 2017</td><td>$ 2.5</td><td>$ 0.6</td><td>$ 0.4</td><td>$ 0.9</td><td>$ 4.4</td></tr></table>

## 23. VARIABLE INTEREST ENTITIES

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 variable interest entities (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.

## 24. QUARTERLY FINANCIAL DATA (UNAUDITED)

<table><tr><td rowspan="3">Eversource (Millions of Dollars, except per share information)</td><td colspan="8">2017</td><td colspan="4">2016</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>March 31,</td><td>June 30,</td><td>September 30,</td><td>December 31,</td></tr><tr><td>Operating Revenues</td><td>$</td><td>2,105.1</td><td>$</td><td>1,762.8</td><td>$</td><td>1,988.5</td><td>$</td><td>1,895.6</td><td>$</td><td>2,055.6</td><td>$</td></tr><tr><td>Operating Income</td><td></td><td>509.0</td><td></td><td>455.7</td><td></td><td>502.6</td><td></td><td>450.9</td><td></td><td>488.5</td><td></td><td>423.4</td></tr><tr><td>Net Income</td><td></td><td>261.3</td><td></td><td>232.6</td><td></td><td>262.2</td><td></td><td>239.4</td><td></td><td>246.0</td><td></td><td>205.5</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td></td><td>259.5</td><td></td><td>230.7</td><td></td><td>260.4</td><td></td><td>237.4</td><td></td><td>244.2</td><td></td><td>203.6</td></tr><tr><td>Basic EPS (1)</td><td></td><td>$</td><td>0.82</td><td>$</td><td>0.73</td><td>$</td><td>0.82</td><td>$</td><td>0.75</td><td>$</td><td>0.77</td><td>$</td></tr><tr><td>Diluted EPS (1)</td><td></td><td>$</td><td>0.82</td><td>$</td><td>0.73</td><td>$</td><td>0.82</td><td>$</td><td>0.75</td><td>$</td><td>0.77</td><td>$</td></tr></table>

(1) The summation of quarterly EPS data may not equal annual data due to rounding.

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="8">2017</td><td colspan="4">2016</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>March 31,</td><td colspan="2">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>$</td><td>732.3</td><td>$</td><td>666.6</td><td>$</td><td>774.8</td><td>$</td><td>713.7</td><td>$</td><td>735.3</td><td>$</td><td>679.8</td></tr><tr><td>Operating Income</td><td></td><td>176.0</td><td></td><td>176.0</td><td></td><td>177.5</td><td></td><td>155.6</td><td></td><td>171.5</td><td></td><td>162.1</td></tr><tr><td>Net Income</td><td></td><td>90.2</td><td></td><td>91.3</td><td></td><td>96.1</td><td></td><td>99.1</td><td></td><td>87.0</td><td></td><td>82.9</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>$</td><td>733.8</td><td>$</td><td>704.7</td><td>$</td><td>851.9</td><td>$</td><td>690.2</td><td>$</td><td>742.2</td><td>$</td><td>707.6</td></tr><tr><td>Operating Income</td><td></td><td>161.6</td><td></td><td>182.7</td><td></td><td>234.4</td><td></td><td>128.9</td><td></td><td>142.9</td><td></td><td>159.7</td></tr><tr><td>Net Income</td><td></td><td>83.4</td><td></td><td>95.0</td><td></td><td>125.8</td><td></td><td>70.5</td><td></td><td>71.3</td><td></td><td>81.4</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>$</td><td>253.2</td><td>$</td><td>230.4</td><td>$</td><td>250.0</td><td>$</td><td>248.0</td><td>$</td><td>242.3</td><td>$</td><td>218.5</td></tr><tr><td>Operating Income</td><td></td><td>68.3</td><td></td><td>64.9</td><td></td><td>67.4</td><td></td><td>71.2</td><td></td><td>70.7</td><td></td><td>63.1</td></tr><tr><td>Net Income</td><td></td><td>34.3</td><td></td><td>31.6</td><td></td><td>33.7</td><td></td><td>36.4</td><td></td><td>36.1</td><td></td><td>31.3</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, 2017.

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, 2017 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.

On December 4, 2017, Eversource completed the acquisition of Eversource Aquarion Holdings, Inc. (formerly Macquarie Utilities Inc.). Eversource Aquarion Holdings Inc. is the parent company that holds the operating companies of the Aquarion water business (collectively, "Aquarion"). As of December 31, 2017, Eversource management has excluded Aquarion from its evaluation of disclosure controls and procedures and management's report on internal controls over financial reporting.

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, 2017 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, 2017, as this information has been previously disclosed in applicable reports on Form 8-K during the fourth quarter of 2017.



## PART III

## Item 10. Directors, Executive Officers and Corporate Governance

The information in Item 10 is provided as of February 23, 2018, 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 “Section 16(a) Beneficial Ownership Reporting Compliance” of Eversource Energy’s definitive proxy statement for solicitation of proxies, expected to be filed with the SEC on or about March 23, 2018.

## 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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. 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 23, 2018, 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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. 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 23, 2018.

## 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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. 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, 2017, 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>1,227,604</td><td>$—</td><td>2,445,110</td></tr><tr><td>Equity compensation plans not approved by security holders (3)</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Total</td><td>1,227,604</td><td>$—</td><td>2,445,110</td></tr></table>

(1) Includes 717,039 common shares for distribution in respect of restricted share units, and 510,565 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 23, 2018.

## 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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. 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 23, 2018.

## 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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. 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, 2017 and 2016

Eversource Energy (Parent) Statements of Income for the Years Ended December 31, 2017, 2016 and 2015

Eversource Energy (Parent) Statements of Comprehensive Income for the Years Ended December 31, 2017, 2016 and 2015

Eversource Energy (Parent) Statements of Cash Flows for the Years Ended December 31, 2017, 2016 and 2015

II. Valuation and Qualifying Accounts and Reserves for Eversource, CL&P, NSTAR Electric and PSNH for 2017, 2016 and 2015

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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. Such report is also available in the Investors section at www.eversource.com.

## Item 16. Form 10-K Summary

Not applicable.



# 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 23, 2018

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 23, 2018</td></tr><tr><td>James J. Judge</td><td></td><td></td></tr><tr><td>/s/ Philip J. Lembo</td><td>Executive Vice President and Chief Financial Officer (Principal Financial Officer)</td><td>February 23, 2018</td></tr><tr><td>Philip J. Lembo</td><td></td><td></td></tr><tr><td>/s/ Jay S. Buth</td><td>Vice President, Controller and Chief Accounting Officer</td><td>February 23, 2018</td></tr><tr><td>Jay S. Buth</td><td></td><td></td></tr><tr><td>/s/ John S. Clarkeson</td><td>Trustee</td><td>February 23, 2018</td></tr><tr><td>John S. Clarkeson</td><td></td><td></td></tr><tr><td>/s/ Cotton M. Cleveland</td><td>Trustee</td><td>February 23, 2018</td></tr><tr><td>Cotton M. Cleveland</td><td></td><td></td></tr><tr><td>/s/ Sanford Cloud, Jr.</td><td>Trustee</td><td>February 23, 2018</td></tr><tr><td>Sanford Cloud, Jr.</td><td></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 23, 2018</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 23, 2018</td></tr><tr><td>Francis A. Doyle</td><td></td><td></td></tr><tr><td>/s/ Charles K. Gifford</td><td>Trustee</td><td>February 23, 2018</td></tr><tr><td>Charles K. Gifford</td><td></td><td></td></tr><tr><td>/s/ John Y. Kim</td><td>Trustee</td><td>February 23, 2018</td></tr><tr><td>John Y. Kim</td><td></td><td></td></tr><tr><td>/s/ Paul A. La Camera</td><td>Trustee</td><td>February 23, 2018</td></tr><tr><td>Paul A. La Camera</td><td></td><td></td></tr><tr><td>/s/ Kenneth R. Leibler</td><td>Trustee</td><td>February 23, 2018</td></tr><tr><td>Kenneth R. Leibler</td><td></td><td></td></tr><tr><td>/s/ William C. Van Faasen</td><td>Trustee</td><td>February 23, 2018</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 23, 2018</td></tr><tr><td>Frederica M. Williams</td><td></td><td></td></tr><tr><td>/s/ Dennis R. Wraase</td><td>Trustee</td><td>February 23, 2018</td></tr><tr><td>Dennis R. Wraase</td><td></td><td></td></tr></table>



## 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 2017 filed with the SEC on a combined basis with Eversource Energy on February 26, 2018. Such report is also available in the Investors section at www.eversource.com.

Exhibit Number ___ Description ___

3. Articles of Incorporation and By-Laws

(A) Eversource Energy

3.1 Declaration of Trust of Eversource Energy, as amended through May 3, 2017 (Exhibit 3.1, Eversource Form 10-Q filed on May 5, 2017)

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

(A) Eversource Energy

4.1 Indenture between Eversource Energy and The Bank of New York as Trustee dated as of April 1, 2002 (Exhibit A-3, Eversource Energy 35-CERT filed April 16, 2002, File No. 070-09535)

4.1.1 Fifth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of May 1, 2013, relating to $300 million of Senior Notes, Series E, due 2018 and $4 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 $150 million of Senior Notes, Series G, due 2018 and $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)

4.2 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)

(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



(A) Eversource Energy

* 10.1 Lease between The Rocky River Realty Company and Eversource Energy Service Company, dated as of July 1, 2008

+ 10.2 Eversource Energy Board of Trustees' Compensation Arrangement Summary (Exhibit 10.3, 2016 Eversource Energy Form 10-K filed February 23, 2017, File No. 001-05324)

+ 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 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 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)

+ 10.7 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 NSTAR 2007 Long Term Incentive Plan, effective May 3, 2007 (Exhibit 10.2, Eversource Energy Registration Statement on Form S-8 filed on May 8, 2012)

+ 10.8.1 Deferred Common Share/Dividend Equivalent Award, Stock Option Grant, Option Certificate and Performance Share Award/Dividend Equivalent Award Agreement Under the NSTAR 2007 Long Term Incentive Plan, by and between NSTAR and James J. Judge, dated January 24, 2008 (Exhibit 10.8.2, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+ 10.8.2 Deferred Common Share/Dividend Equivalent Award, Stock Option Grant, Option Certificate and Performance Share Award/Dividend Equivalent Award Agreement Under the NSTAR 2007 Long Term Incentive Plan, by and between NSTAR and Joseph R. Nolan, dated January 24, 2008 (Exhibit 10.8.4, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+ 10.8.3 Deferred Common Share/Dividend Equivalent Award, Stock Option Grant, Option Certificate and Performance Share Award/Dividend Equivalent Award Agreement Under the NSTAR 2007 Long Term Incentive Plan, by and between NSTAR and Werner J. Schweiger, dated January 24, 2008 (Exhibit 10.8.5, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+ 10.8.4 Deferred Common Share/Dividend Equivalent Award, Stock Option Grant, Option Certificate and Performance Share Award/Dividend Equivalent Award Agreement Under the NSTAR 2007 Long Term Incentive Plan by and between NSTAR and NSTAR's other Senior Vice Presidents and Vice Presidents, dated January 24, 2008 (in form) (Exhibit 10.8.6, 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 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)

+ 10.10 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)

+ 10.11 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)

+ 10.12 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)



+ 10.13 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)

+ 10.14 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)

(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 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)

+ 10.5.1 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)

+ 10.5.2 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)

+ 10.6 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)

+ 10.7 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, Inc., dated as of June 1, 1985 (Massachusetts)

* 10.1.2 Composite conformed copy of Equity Funding Agreement for New England Hydro-Transmission Electric Company, Inc., dated as of June 1, 1985 (New Hampshire)

* 10.1.3 Composite conformed copy of Phase II Massachusetts Transmission Facilities Support Agreement, dated as of June 1, 1985

* 10.1.4 Composite conformed copy of Phase II New England Power AC Facilities Support Agreement dated June 1, 1985

* 10.1.5 Composite conformed copy of Phase II New Hampshire Transmission Facilities Support Agreement dated as of June 1, 1985



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)

(E) Eversource Energy and Public Service Company of New Hampshire

* 10.1 Purchase and Sale Agreement between Public Service Company of New Hampshire and Granite Shore Power LLC, dated as of October 11, 2017

* 10.2 Purchase and Sale Agreement between Public Service Company of New Hampshire and HSE Hydro NH AC, LLC dated as of October 11, 2017

* 12. Ratio of Earnings to Fixed Charges

* 21. Subsidiaries of the Registrant

* 23. Consents of Independent Registered Public Accounting Firm

* 31. Rule 13a - 14(a)/15 d - 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 XBRL Instance Document

* 101.SCH XBRL Taxonomy Extension Schema

* 101.CAL XBRL Taxonomy Extension Calculation

* 101.DEF XBRL Taxonomy Extension Definition

* 101.LAB XBRL Taxonomy Extension Labels

* 101.PRE XBRL Taxonomy Extension Presentation



# 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 23, 2018

/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 23, 2018

/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, 2017 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 23, 2018

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

## John S. Clarkeson

Chairman Emeritus,
The Boston Consulting Group, Inc.

## 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

President and Chief Executive Officer,
Connell Limited Partnership

## Charles K. Gifford

Chairman Emeritus,
Bank of America Corporation

## John Y. Kim

President,
New York Life Insurance Company

## Paul A. La Camera

Administrator,
Public Radio at Boston University/WBUR
Boston

## Kenneth R. Leibler

Vice Chairman,
The Putnam Mutual Funds

## 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

## Dennis R. Wraase

Retired Chairman of the Board,
President and Chief Executive Officer,
Pepco Holdings, Inc.

* 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 – Customer and Corporate Relations

## Leon J. Olivier

Executive Vice President –
Enterprise Energy Strategy and Business Development

## Werner J. Schweiger

Executive Vice President and Chief Operating Officer



## Shareholder Information

## Shareholders

As of December 31, 2017, there were 37,567 common shareholders of record of Eversource Energy holding an aggregate of 316,885,808 common shares.

## Transfer Agent and Registrar

Computershare Investor Services
P.O. Box 43078
Providence, RI 02940-3078

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/investors

## Dividend Reinvestment Plan

Eversource offers a dividend reinvestment 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 of 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">2017</td><td>First</td><td>$60.36</td><td>$54.08</td><td>$0.4750</td></tr><tr><td>Second</td><td>$63.34</td><td>$58.11</td><td>$0.4750</td></tr><tr><td>Third</td><td>$64.19</td><td>$59.55</td><td>$0.4750</td></tr><tr><td>Fourth</td><td>$66.15</td><td>$59.59</td><td>$0.4750</td></tr><tr><td rowspan="4">2016</td><td>First</td><td>$58.81</td><td>$50.01</td><td>$0.4450</td></tr><tr><td>Second</td><td>$59.95</td><td>$53.90</td><td>$0.4450</td></tr><tr><td>Third</td><td>$60.44</td><td>$53.08</td><td>$0.4450</td></tr><tr><td>Fourth</td><td>$55.74</td><td>$50.56</td><td>$0.4450</td></tr></table>

## Corporate Governance

For information on Corporate Governance at Eversource, go to our website, www.eversource.com, and select “Investors” and then “Corporate Governance.”



#1 ranked U.S. utility in the nation for its energy efficiency programs by Ceres

Newsweek ranked Eversource in top 20 out of 500 U.S. companies in 2017 Green Rankings list

Eversource received 2017 EEI Award for storm support for Hurricane Irma

Forbes Magazine included Eversource in its list of America’s Best Employers