Eversource Energy (ES, NYSE)
Industry: Utilities - Regulated Electric
Annual report, fiscal year 2015


## 2015
Annual Report







EVERS \( ^{®} \)  URCE
ENERGY






Total Shareholder Return






<table><tr><td></td><td>2015</td><td>2014</td></tr><tr><td>Operating Revenues</td><td>$ 7,954,827</td><td>$ 7,741,856</td></tr><tr><td>Operating Income</td><td>$ 1,764,164</td><td>$ 1,632,849</td></tr><tr><td>Net Income Attributable to ES Common Shares</td><td>$ 878,485</td><td>$ 819,546</td></tr><tr><td>Diluted Earnings per Common Share (GAAP)</td><td>$ 2.76</td><td>$ 2.58</td></tr><tr><td>Diluted Earnings per Common Share (Non-GAAP) (1)</td><td>$ 2.81</td><td>$ 2.65</td></tr><tr><td>Diluted Common Shares Outstanding (Weighted Average)</td><td>318,432,687</td><td>317,417,414</td></tr><tr><td>Dividends Paid per Share</td><td>$ 1.67</td><td>$ 1.57</td></tr><tr><td>Sales of Electricity (Regulated Retail, kWh-millions)</td><td>54,616</td><td>54,442</td></tr><tr><td>Electric Customers (As of Year End)</td><td>3,139,608</td><td>3,119,675</td></tr><tr><td>Firm Sales of Natural Gas (million cubic feet)</td><td>98,458</td><td>99,500</td></tr><tr><td>Natural Gas Customers (As of Year End)</td><td>511,288</td><td>500,703</td></tr><tr><td>Investments in Property, Plant and Equipment</td><td>$ 1,724,139</td><td>$ 1,603,744</td></tr><tr><td>Property, Plant and Equipment, Net (As of Year End)</td><td>$ 19,892,441</td><td>$ 18,647,041</td></tr><tr><td>Market Capitalization (As of Year End)</td><td>$ 16,198,957</td><td>$ 16,964,948</td></tr><tr><td>Share Price (As of Year End)</td><td>$ 51.07</td><td>$ 53.52</td></tr></table>

(1) Diluted Earnings per Common Share (Non-GAAP) was adjusted to exclude integration-related costs. See Item 7, "Management's Discussion and Analysis of Financial Condition and Results of Operations," in the accompanying Form 10-K for a reconciliation to GAAP.

## Company Profile

Eversource Energy (NYSE:ES), a Fortune 500 and Standard & Poor's 500 energy company based in Connecticut, Massachusetts and New Hampshire, operates New England's largest energy delivery system. Eversource is committed to safety, reliability, environmental leadership and stewardship, and expanding energy options for its 3.6 million electricity and natural gas customers.

## Eversource Service Territory

Electric

Gas

Combined Electric and Gas






By remaining faithful to our core mission to safely deliver reliable energy and superior customer service, Eversource has been able to consistently provide significant value to our customers, communities and shareholders.

We have been thoughtful and innovative when it comes to meeting our customers' evolving needs, delivering top-quartile reliability and addressing New England's energy challenges. Our approach of smart system investments, customer service excellence and conservative financial management has enhanced our customer service, provided strong leadership in the industry, and delivered a very attractive level of earnings and dividend growth.

In 2015, we reported recurring earnings of $2.81 per share, compared with recurring earnings of $2.65 in 2014, an increase of six percent driven largely by higher retail electric and transmission revenue, and effective cost discipline. That growth is consistent with our longer term projected annual earnings per share growth rate of five to seven percent, which is one of the most attractive growth rates in the electric utility industry.

Our earnings growth also supports solid dividend growth for our shareholders. In 2015, we raised our common dividend by 6.4 percent to an annualized rate of $1.67 per share, and in February 2016 we announced a 6.6 percent increase in the common dividend to an annualized rate of $1.78 per share.

Strong earnings and dividend growth have benefited our share price. Over the past five years, Eversource has provided a cumulative total return to our shareholders of 89 percent, which compares favorably to a 71 percent total five-year return for the Edison Electric Institute Index and an 81 percent total return for the S&P 500.

We are achieving these returns while at the same time effectively managing our financial and operating risks. In April, Standard and Poor's Ratings Services raised its corporate credit rating for the Eversource family of companies to "A" with a stable outlook, the top rating among our electric utility peers. Also in 2015, Moody's Investor Services and Fitch Ratings raised the outlook on multiple Eversource operating subsidiaries to "positive" from "stable." Strong credit ratings lower interest costs, benefiting both customers and shareholders.



Our strong financial performance has been a direct result of our outstanding operating performance, highlighted by our best year ever for electric reliability. Since 2011, Eversource's frequency of electric service interruptions, and the amount of time it takes to restore customers' power when outages occur, have both decreased by about 40 percent. We have established an improved enterprise-wide organizational model for our operations team, and have successfully implemented a state-of-the-art electric distribution management platform. This platform automates the control and operation of our grid using self-healing technology, enhances customer communication, and enables a consistent customer experience across all three states. We continue to invest heavily in our electric distribution system, with capital expenditures totaling a record $783 million in 2015, up nearly 8 percent from 2014 levels. That level of investment, coupled with our ongoing implementation of best practices and procedures, is driving our performance steadily higher within the top quartile of our industry.

This performance was particularly impressive during arguably one of the worst winters in history. Record-breaking snowstorm after snowstorm in early 2015 battered Boston, Cape Cod and the island of Martha's Vineyard, as well as parts of Connecticut and New Hampshire. Our dedicated team of employees and “one company” coordination across all three states served to create an exceptional storm response.




It is during these cold winters when the serious energy challenges facing New England are most apparent. Natural gas is the fuel of choice for heating and power production and non-gas-fired power plants continue to retire, yet no major additions to our region’s natural gas transmission infrastructure have occurred in at least 20 years. We cannot continue to endure winter gas delivery constraints, which produce volatile energy markets and the potential for skyrocketing prices like we have experienced in many recent winters.

Eversource understands the region’s dilemma and has taken the lead in addressing it. Two of our projects, Access Northeast and Northern Pass, will provide New England customers with significant relief by expanding pipeline capacity, importing clean hydro power and creating long-term cost savings. I am pleased to report both projects gained solid ground in 2015. Access Northeast has begun the federal regulatory approval process. It has also signed long-term gas supply contracts with electric distribution companies that are now being reviewed by regulators.

Northern Pass revised its 192-mile route, adding 52 miles of underground construction in scenic areas, commenced the state regulatory review process, received a favorable draft environmental impact statement from the U.S. Department of Energy, and released its new Forward NH Plan that underscores the billions of dollars in project benefits to the state of New Hampshire.

These projects will both provide significant economic and environmental benefits to New England, lowering our dependence on older, higher emitting oil and coal-fired generation. Once Access Northeast is in service, we have estimated New Englanders could save 1.5 to 2 billion annually in energy costs during normal winter weather. Further, we have estimated the additional 1,090 MW of base load power Northern Pass will bring to the region would save New England customers more than 800 million per year. Customers need and deserve this price stability. Moreover, Northern Pass alone is expected to lower carbon emissions in New England by at least 3 million tons annually—that’s the equivalent of taking more than 600,000 cars off the road.



In addition to Northern Pass, we continue to invest heavily in electric transmission projects that maintain the reliability of the region’s electric grid. The Interstate Reliability Project (IRP) was completed in 2015, successfully capping off nearly a decade of planning, siting and construction of the New England East-West Solution (NEWS)—a suite of regional projects designed to strengthen the reliability of the regional power grid by improving efficiency and eliminating congestion. The investment by Eversource alone in NEWS was approximately 1 billion.

NEWS projects represent the largest upgrade to the regional transmission system in a number of years, supporting the region’s economic growth and environmental goals through greater access to newer, more efficient, and cleaner generating plants. In 2015, we commenced siting filings and construction on our next two major transmission initiatives, the Greater Boston and Greater Hartford sets of reliability projects. Altogether, we expect to invest approximately 900 million in these initiatives by 2019.

We are also investing heavily in our natural gas delivery infrastructure—$213 million in 2015 and nearly $1.3 billion projected from 2016 through 2019. That investment involves a combination of upgrading existing distribution mains and LNG storage facilities, and meeting the increasing demand in our




communities for natural gas heat. In 2015, a record 11,415
Eversource customers in Connecticut and Massachusetts installed
natural gas space heating in their homes and businesses, and we
expect that figure to climb to 12,500 in 2016.

Energy efficiency investments and customer programs continue to be critical to our company’s long-term success. We invested $500 million last year alone in efficiency programs that truly benefit our customers. And the measures we have helped install for customers will save 11 billion kWh of electricity and 130 million therms of natural gas over their lifetime, as well as eliminate the emission of 5 million tons of carbon. Those savings represent enough electricity to power 1.3 million homes for a year and enough natural gas to heat 140,000 New England homes for a year.

Investments in our community also are a large component of how we deliver great service to customers. We have two clear priorities: focusing on health and well-being of youth in our service territory, and making sure that our giving has a wide impact. As the largest energy provider in the region, we want to reach as many of our fellow New Englanders as possible. In 2015, Eversource's philanthropy totaled approximately $5 million, through direct program grants, partnerships like the Eversource Hartford Marathon, the Eversource Walk for Boston Children's Hospital, or Special Olympics, and employee volunteerism and giving programs like our United Way Campaign.

Looking ahead to 2016, our focus on the customer in all that we do also means helping them understand how we are working diligently to change the energy landscape in the region. Last year, Eversource conducted comprehensive customer research, asking customers about their perceptions of the company, including our delivery of service, the cost of energy and our role in overall energy prices. What we learned was clear: customers know who Eversource is, and feel we are doing a great job in reliably delivering their energy.



We also learned that wide fluctuations in energy prices negatively impact customers' satisfaction with Eversource. Most customers do not understand the current market dynamics, the effect of those dynamics on their bills, or the important work Eversource is doing to resolve the region's energy dilemma.

Taking this research into consideration, we are now changing the conversation with customers, while also aiming to drive customer satisfaction improvements. It’s a new and exciting approach to customer communication and education, using a combination of advertising, interactive online experiences, call center scripting, a new bill, and social media. We are helping them understand why energy prices go up and down and what steps they can take to reduce their costs. We believe this initiative will improve customer satisfaction scores, which in turn helps drive the overall success of the company.

We are firmly in the driver’s seat when it comes to energy delivery in New England. We are the region’s premier gas and electric provider, but more than that, we are an advocate for our customers, with strong leadership and solutions to pricing and supply challenges. Eversource has an exciting future ahead as our company continues to thrive and grow.






# 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, 2015

or

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

For the transition period from ___ to ___

Commission
File Number
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: (413) 785-5871
04-2147929

0-00404
THE CONNECTICUT LIGHT AND POWER COMPANY
(a Connecticut corporation)
107 Selden Street
Berlin, Connecticut 06037-1616
Telephone: (860) 665-5000
06-0303850

1-02301
NSTAR ELECTRIC COMPANY
(a Massachusetts corporation)
800 Boylston Street
Boston, Massachusetts 02199
Telephone: (617) 424-2000
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: (603) 669-4000
02-0181050

0-7624
WESTERN MASSACHUSETTS ELECTRIC COMPANY
(a Massachusetts corporation)
300 Cadwell Drive
Springfield, Massachusetts 01104
Telephone: (413) 785-5871
04-1961130



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

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

<table><tr><td>4.25%</td><td>Series</td></tr><tr><td>4.78%</td><td>Series</td></tr></table>

NSTAR Electric Company, Public Service Company of New Hampshire and Western Massachusetts Electric Company 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) to 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 registrant was 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, or a non-accelerated filer. See definition of “accelerated filer” and “large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):

<table><tr><td rowspan="2"></td><td>Large Accelerated Filer</td><td>Accelerated Filer</td><td>Non-accelerated Filer</td></tr><tr><td>☒</td><td>☐</td><td>☐</td></tr><tr><td>Eversource Energy</td><td>☐</td><td>☐</td><td>☒</td></tr><tr><td>The Connecticut Light and Power Company</td><td>☐</td><td>☐</td><td>☒</td></tr><tr><td>NSTAR Electric Company</td><td>☐</td><td>☐</td><td>☒</td></tr><tr><td>Public Service Company of New Hampshire</td><td>☐</td><td>☐</td><td>☒</td></tr><tr><td>Western Massachusetts Electric Company</td><td>☐</td><td>☐</td><td>☒</td></tr></table>

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><tr><td>Western Massachusetts Electric Company</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, 2015) was $14,345,789,335 based on a closing market price of $45.41 per share for the 315,916,964 common shares outstanding on June 30, 2015.

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, 2016</td></tr><tr><td>Eversource Energy</td><td></td></tr><tr><td>Common shares, $5.00 par value</td><td>317,191,249 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>100 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><tr><td>Western Massachusetts Electric Company</td><td></td></tr><tr><td>Common stock, $25.00 par value</td><td>434,653 shares</td></tr></table>

Eversource Energy holds all of the 6,035,205 shares, 100 shares, 301 shares, and 434,653 shares of the outstanding common stock of The Connecticut Light and Power Company, NSTAR Electric Company, Public Service Company of New Hampshire and Western Massachusetts Electric Company, respectively.

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



## GLOSSARY OF TERMS

The following is a glossary of abbreviations or 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</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>WMECO</td><td>Western Massachusetts Electric Company</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>NPT</td><td>Northern Pass Transmission LLC</td></tr><tr><td>Eversource Service</td><td>Eversource Energy Service Company (effective January 1, 2014 includes the operations of NSTAR Electric &amp; Gas)</td></tr><tr><td>NSTAR Electric &amp; Gas</td><td>NSTAR Electric &amp; Gas Corporation, a former Eversource Energy service company (effective January 1, 2014 merged into Eversource Energy Service Company)</td></tr><tr><td>CYAPC</td><td>Connecticut Yankee Atomic Power Company</td></tr><tr><td>MYAPC</td><td>Maine Yankee Atomic Power Company</td></tr><tr><td>YAEC</td><td>Yankee Atomic Electric Company</td></tr><tr><td>Yankee Companies</td><td>CYAPC, YAEC and MYAPC</td></tr><tr><td>Regulated companies</td><td>The Eversource Regulated companies are comprised of the electric distribution and transmission businesses of CL&amp;P, NSTAR Electric, PSNH, and WMECO, the natural gas distribution businesses of Yankee Gas and NSTAR Gas, the generation activities of PSNH and WMECO, and NPT</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>AFUDC</td><td>Allowance For Funds Used During Construction</td></tr><tr><td>AOCI</td><td>Accumulated Other Comprehensive Income/(Loss)</td></tr><tr><td>ARO</td><td>Asset Retirement Obligation</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 “scrubber technology,” 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>EPS</td><td>Earnings Per Share</td></tr><tr><td>ERISA</td><td>Employee Retirement Income Security Act of 1974</td></tr><tr><td>ES 2014 Form 10-K</td><td>The Eversource Energy and Subsidiaries 2014 combined Annual Report on Form 10-K as filed with the SEC</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>FERC ALJ</td><td>FERC Administrative Law Judge</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></table>



<table><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>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>NEWS</td><td>New England East-West Solution</td></tr><tr><td>Northern Pass</td><td>The high voltage direct current transmission line project from Canada into New Hampshire</td></tr><tr><td>NOx</td><td>Nitrogen oxides</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>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
WESTERN MASSACHUSETTS ELECTRIC COMPANY

## 2015 FORM 10-K ANNUAL REPORT

## TABLE OF CONTENTS

## Page

## PART I

Item 1. Business 2
Item 1A. Risk Factors 16
Item 1B. Unresolved Staff Comments 19
Item 2. Properties 19
Item 3. Legal Proceedings 21
Item 4. Mine Safety Disclosures 22

## PART II

Item 5. Market for the Registrants' Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities 24
Item 6. Selected Consolidated Financial Data 26
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations 28
Item 7A. Quantitative and Qualitative Disclosures about Market Risk 50
Item 8. Financial Statements and Supplementary Data 51
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure 103
Item 9A. Controls and Procedures 103
Item 9B. Other Information 103

## PART III

Item 10. Directors, Executive Officers and Corporate Governance 104
Item 11. Executive Compensation 104
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters 104
Item 13. Certain Relationships and Related Transactions, and Director Independence 105
Item 14. Principal Accountant Fees and Services 105

## PART IV

Item 15. Exhibits and Financial Statement Schedules 106
Signatures 107



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

# 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 and its consolidated subsidiaries. On April 30, 2015, the Company’s legal name was changed from Northeast Utilities to Eversource Energy. CL&P, NSTAR Electric, PSNH and WMECO 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, acts of war or terrorism, or grid disturbances,

• 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,

• 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,

• 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, contain uncertainties that may materially affect our actual results and are beyond our control. You should not place undue reliance on the forward-looking statements, each speaks only as of the date on which such statement is made, and 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 Consolidated 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
WESTERN MASSACHUSETTS ELECTRIC COMPANY

## 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 Massachusetts;

- 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;

- Western Massachusetts Electric Company (WMECO), a regulated electric utility that serves residential, commercial and industrial customers in parts of western Massachusetts and owns solar generating assets;

- 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.

CL&P, NSTAR Electric, PSNH and WMECO also serve New England customers through Eversource Energy’s electric transmission business.

On April 30, 2015, the Company’s legal name was changed from Northeast Utilities to Eversource Energy. CL&P, NSTAR Electric, PSNH and WMECO are each doing business as Eversource Energy.

Eversource Energy, CL&P, NSTAR Electric, PSNH and WMECO 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 generation businesses of PSNH and WMECO. These three segments represented substantially all of Eversource Energy’s total consolidated revenues for the years ended December 31, 2015 and 2014. CL&P, NSTAR Electric, PSNH and WMECO 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, PSNH and WMECO, which are engaged in the distribution of electricity to retail customers in Connecticut, eastern Massachusetts, New Hampshire and western Massachusetts, respectively, plus the regulated electric generation businesses of PSNH and WMECO.

The following table shows the sources of 2015 electric franchise retail revenues for Eversource Energy’s electric distribution companies, collectively, based on categories of customers:

<table><tr><td>(Thousands of Dollars, except percentages)</td><td>2015</td><td>% of Total</td></tr><tr><td>Residential</td><td>$ 3,608,155</td><td>55</td></tr><tr><td>Commercial</td><td>2,476,686</td><td>38</td></tr><tr><td>Industrial</td><td>326,564</td><td>5</td></tr><tr><td>Other</td><td>151,195</td><td>2</td></tr><tr><td>Total Retail Electric Revenues</td><td>$ 6,562,600</td><td>100%</td></tr></table>



A summary of our distribution companies' retail electric GWh sales volumes and percentage changes for 2015, as compared to 2014, is as follows:

<table><tr><td></td><td>2015</td><td>2014</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>21,441</td><td>21,317</td><td>0.6%</td></tr><tr><td>Commercial</td><td>27,598</td><td>27,449</td><td>0.5%</td></tr><tr><td>Industrial</td><td>5,577</td><td>5,676</td><td>(1.7)%</td></tr><tr><td>Total</td><td>54,616</td><td>54,442</td><td>0.3%</td></tr></table>

Our 2015 consolidated retail electric sales volumes were slightly higher, as compared to 2014, due primarily to the impact of colder winter weather experienced in the first quarter of 2015 and warmer weather in the third quarter of 2015, partially offset by milder winter weather in the fourth quarter of 2015 throughout our service territories as well as an increase in customer conservation efforts, including the impact of energy efficiency programs sponsored by CL&P, NSTAR Electric, PSNH and WMECO.

Fluctuations in retail electric sales volumes at NSTAR Electric and PSNH impact earnings. For CL&P (effective December 1, 2014) and WMECO, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission approved revenue decoupling mechanisms. These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized. CL&P and WMECO reconcile their annual base distribution rate recovery amounts to their respective pre-established levels of baseline distribution delivery service revenues. Any difference between the allowed level of distribution revenue and the actual amount incurred during a 12-month period is adjusted through rates in the following period.

## 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, 2015, 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 2015 electric franchise retail revenues based on categories of customers:

<table><tr><td rowspan="2">(Thousands of Dollars, except percentages)</td><td colspan="2">CL&amp;P</td></tr><tr><td>2015</td><td>% of Total</td></tr><tr><td>Residential</td><td>$ 1,641,165</td><td>61</td></tr><tr><td>Commercial</td><td>841,093</td><td>31</td></tr><tr><td>Industrial</td><td>129,544</td><td>5</td></tr><tr><td>Other</td><td>62,704</td><td>3</td></tr><tr><td>Total Retail Electric Revenues</td><td>$ 2,674,506</td><td>100%</td></tr></table>

A summary of CL&P’s retail electric GWh sales volumes and percentage changes for 2015, as compared to 2014, is as follows:

<table><tr><td rowspan="2"></td><td colspan="2">Percentage</td></tr><tr><td>2015</td><td>2014</td></tr><tr><td>Residential</td><td>10,094</td><td>10,026</td></tr><tr><td>Commercial</td><td>9,635</td><td>9,643</td></tr><tr><td>Industrial</td><td>2,342</td><td>2,377</td></tr><tr><td>Total</td><td>22,071</td><td>22,046</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, renewables, CTA, SBC and other charges that are assessed on all customers. Connecticut utilities are entitled under state law to charge rates that are sufficient to allow them an opportunity to recover their reasonable operating and capital costs, in order to attract needed capital and maintain their financial integrity, while also protecting relevant public interests.

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, and LRS rates for customers with 500 kilowatts or more of demand, CL&P purchases power under standard offer contracts and passes the cost of the power to customers through a combined GSC and FMCC charge on customers’ bills.

CL&P continues to supply approximately 40 percent of its customer load at SS or LRS rates while the other 60 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.



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

- An electric generation services charge (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 (effective December 1, 2014) 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 power to customers, as well as ongoing operating costs to maintain the infrastructure.

- A federally-mandated congestion charge (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 competitive transition assessment charge (CTA), 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.

- A systems benefits charge (SBC), established to fund expenses associated with: various hardship and low income programs; a program to compensate municipalities for losses in property tax revenue due to decreases in the value of electric generating facilities resulting directly from 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 charge):

- Four 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 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).

- Long-term commitments to purchase approximately 250 MW of wind power from a Maine wind farm and 20 MW of solar power from a multi-site project in Connecticut. Both of these projects are expected to be operational by the end of 2016.

On December 17, 2014 the PURA approved CL&P’s application to amend customer rates, effective December 1, 2014, for a total base distribution rate increase of $152 million, which includes an authorized ROE of 9.02 percent for the first twelve month period and 9.17 percent thereafter. The distribution rate increase included a revenue decoupling mechanism effective December 1, 2014, and the recovery of 2011 and 2012 storm restoration costs and system resiliency costs. Also in December 2014, the PURA granted a re-opener request to CL&P’s base distribution rate application for further review of the appropriate balance of ADIT utilized in the calculation of rate base. On July 2, 2015, the PURA issued a final order that approved a settlement agreement filed on May 19, 2015 between CL&P and the PURA Prosecutorial Staff, and which included an increase to total allowed annual revenue requirements of $18.4 million beginning December 1, 2014.



## 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 periodically enters into full requirements contracts for the majority of SS loads for periods of up to one year for its residential customers and small and medium commercial and industrial customers. CL&P is authorized to supply the remainder of the SS loads through a self-managed process that includes bilateral purchases and spot market purchases. CL&P typically enters into full requirements contracts for LRS for larger commercial and industrial customers every three months. Currently, CL&P has full requirements contracts in place for 80 percent of its SS loads for the first half of 2016 and has bilateral purchases in place to self-manage the remaining 20 percent. For the second half of 2016, CL&P has 50 percent of its SS load under full requirements contracts, intends to purchase an additional 30 percent of full requirements and will self-manage the remainder as needed. None of the SS load for 2017 has been procured. CL&P has full requirements contracts in place for its LRS loads through the second quarter of 2016 and intends to purchase 100 percent of full requirements for the third and fourth quarters of 2016.

## ELECTRIC DISTRIBUTION – MASSACHUSETTS

## NSTAR ELECTRIC COMPANY

## WESTERN MASSACHUSETTS ELECTRIC COMPANY

The electric distribution businesses of NSTAR Electric and WMECO consist primarily of the purchase, delivery and sale of electricity to residential, commercial and industrial customers within their respective franchise service territories. As of December 31, 2015, NSTAR Electric furnished retail franchise electric service to approximately 1.2 million customers in Boston and 80 surrounding cities and towns in Massachusetts, including Cape Cod and Martha's Vineyard, covering an area of approximately 1,700 square miles. WMECO provides retail franchise electric service to approximately 209,000 customers in 59 cities and towns in the western region of Massachusetts, covering an area of approximately 1,500 square miles. Neither NSTAR Electric nor WMECO owns any generating facilities used to supply customers, and each purchases its respective energy requirements from competitive energy suppliers.

In 2009, WMECO was authorized by the DPU to install solar energy generation in its service territory. From 2010 through 2014, WMECO completed development of a total of 8 MW solar generation facilities on sites in Pittsfield, Springfield, and East Springfield, Massachusetts. WMECO will sell all energy and other products from its solar generation facilities into the ISO-NE market. NSTAR Electric does not own any solar generation facilities.

The following table shows the sources of the 2015 electric franchise retail revenues of NSTAR Electric and WMECO based on categories of customers:

<table><tr><td rowspan="2">(Thousands of Dollars, except percentages)</td><td colspan="2">NSTAR Electric</td><td colspan="2">WMECO</td></tr><tr><td>2015</td><td>% of Total</td><td>2015</td><td>% of Total</td></tr><tr><td>Residential</td><td>$ 1,205,387</td><td>48</td><td>$ 255,797</td><td>59</td></tr><tr><td>Commercial</td><td>1,187,452</td><td>47</td><td>135,222</td><td>31</td></tr><tr><td>Industrial</td><td>84,667</td><td>3</td><td>35,439</td><td>8</td></tr><tr><td>Other</td><td>47,610</td><td>2</td><td>5,778</td><td>2</td></tr><tr><td>Total Retail Electric Revenues</td><td>$ 2,525,116</td><td>100%</td><td>$ 432,236</td><td>100%</td></tr></table>

A summary of NSTAR Electric’s and WMECO’s retail electric GWh sales volumes and percentage changes for 2015, as compared to 2014, is as follows:

<table><tr><td rowspan="2"></td><td colspan="3">NSTAR Electric</td><td colspan="3">WMECO</td></tr><tr><td>2015</td><td>2014</td><td>Percentage Change</td><td>2015</td><td>2014</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>6,687</td><td>6,625</td><td>0.9 %</td><td>1,465</td><td>1,494</td><td>(2.0)%</td></tr><tr><td>Commercial</td><td>13,120</td><td>13,009</td><td>0.9 %</td><td>1,478</td><td>1,466</td><td>0.8 %</td></tr><tr><td>Industrial</td><td>1,248</td><td>1,291</td><td>(3.3)%</td><td>620</td><td>626</td><td>(0.9)%</td></tr><tr><td>Total</td><td>21,055</td><td>20,925</td><td>0.6 %</td><td>3,563</td><td>3,586</td><td>(0.6)%</td></tr></table>

## Rates

NSTAR Electric and WMECO are each 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 both NSTAR Electric and WMECO consists of various rate and service classifications covering residential, commercial and industrial services. Massachusetts utilities are entitled under state law to charge rates that are sufficient to allow them an opportunity to recover their reasonable operating and capital costs, in order to attract needed capital and maintain their financial integrity, while also protecting relevant public interests.

Under Massachusetts law, all customers of each of NSTAR Electric and WMECO are entitled to choose their energy suppliers, while NSTAR Electric or WMECO remains their electric distribution company. Both NSTAR Electric and WMECO purchase power from competitive suppliers on behalf of, and pass the related cost through to, their respective customers who do not choose a competitive energy supplier (basic service). Most of the residential customers of NSTAR Electric and WMECO have continued to buy their power from NSTAR Electric or WMECO 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 39 percent of its customer load at basic service rates while the other 61 percent of its customer load has migrated to competitive energy suppliers. WMECO continues to supply approximately 41 percent of its customer load at basic service rates while the other 59 percent of its customer load has migrated to competitive energy suppliers. Because customer migration is limited to energy supply service, it has no impact on the delivery business or operating income of NSTAR Electric and WMECO.

The rates established by the DPU for NSTAR Electric and WMECO 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 Dynamic Pricing Smart Grid Pilot Program and 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 infrastructure to deliver power to its destination, as well as ongoing operating costs.

- For WMECO, a revenue decoupling adjustment that reconciles distribution revenue, on an annual basis, to the amount of distribution revenue approved by the DPU in its last rate case in 2011. Currently, WMECO is allowed to collect $132.4 million annually.

- 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.

- 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 as follows: pension and PBOP benefits, low income customer discounts, lost revenue and credits associated with net-metering facilities installed by customers, storms, consultants retained by the attorney general, long-term renewable contracts and energy efficiency programs and lost base revenue associated with energy efficiency measures. In addition to these adjustments common to both NSTAR Electric and WMECO, NSTAR Electric has reconciling adjustment charges that collect costs associated with certain safety and reliability projects and a Smart Grid pilot program. WMECO has a reconciling adjustment charge that recovers costs associated with certain solar projects owned and operated by WMECO.

As required by regulation, NSTAR Electric and WMECO, 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. The projects are in various stages of permitting, development, or operation. One unit began operating in late 2015, and the other unit is expected to be in operation by December 2016. In addition, WMECO 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 is expected to be in operation in 2016.

Pursuant to a 2008 DPU order, Massachusetts electric utilities must adopt rate structures that decouple the volume of energy sales from the utility’s revenues in their next rate case. WMECO is currently decoupled and NSTAR Electric will propose decoupling in its next rate case.

NSTAR Electric and WMECO are each 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. Neither NSTAR Electric nor WMECO will be required to pay a SQ charge for its 2015 performance as each company achieved results at or above target for all of its respective SQ metrics in 2015.

## Sources and Availability of Electric Power Supply

As noted above, neither NSTAR Electric nor WMECO owns any generation assets (other than WMECO’s solar generation), and both companies purchase their respective energy requirements from a variety of competitive sources through requests for proposals issued periodically, consistent with DPU regulations. NSTAR Electric and WMECO enter into supply contracts for basic service for 50 percent of their respective residential and small commercial and industrial customers twice per year for twelve month terms. Both NSTAR Electric and WMECO enter 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, 2015, PSNH furnished retail franchise electric service to approximately 503,000 retail customers in 211 cities and towns in New Hampshire, covering an area of approximately 5,630 square miles. PSNH currently owns and operates approximately 1,200 MW of primarily coal-, natural gas-, and oil-fired electricity generation plants. PSNH’s distribution business includes the activities of its generation business.

The Clean Air Project, a wet flue gas desulphurization system (Scrubber), was constructed and placed in service by PSNH at its Merrimack Station in 2011. The Scrubber reduces emissions of SO \( _{2} \)  and mercury from Merrimack Station by over 90 percent, which is well in excess of state and federal requirements. PSNH is permitted to recover prudent Scrubber costs through its default energy service rates under New Hampshire law. Effective January 1, 2016, PSNH is recovering all Scrubber costs in rates charged to customers. For further information, see “Regulatory Developments and Rate Matters – New Hampshire – Clean Air Project Prudence Proceeding” in the accompanying Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following table shows the sources of PSNH’s 2015 electric franchise retail revenues based on categories of customers:

<table><tr><td rowspan="2">(Thousands of Dollars, except percentages)</td><td colspan="2">PSNH</td></tr><tr><td>2015</td><td>% of Total</td></tr><tr><td>Residential</td><td>$ 505,806</td><td>54</td></tr><tr><td>Commercial</td><td>312,918</td><td>34</td></tr><tr><td>Industrial</td><td>76,914</td><td>8</td></tr><tr><td>Other</td><td>35,103</td><td>4</td></tr><tr><td>Total Retail Electric Revenues</td><td>$ 930,741</td><td>100%</td></tr></table>

A summary of PSNH’s retail electric GWh sales volumes and percentage changes for 2015, as compared to 2014, is as follows:

<table><tr><td></td><td>2015</td><td>2014</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>3,195</td><td>3,172</td><td>0.7%</td></tr><tr><td>Commercial</td><td>3,365</td><td>3,332</td><td>1.0%</td></tr><tr><td>Industrial</td><td>1,367</td><td>1,382</td><td>(1.1)%</td></tr><tr><td>Total</td><td>7,927</td><td>7,886</td><td>0.5%</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. New Hampshire utilities are entitled under state law to charge rates that are sufficient to allow them an opportunity to recover their reasonable operating and capital costs, in order to attract needed capital and maintain their financial integrity, while also protecting relevant public interests.

Under New Hampshire law, all of PSNH’s customers are entitled to choose competitive energy suppliers, with PSNH providing default energy service under its ES rate for those customers who do not choose a competitive energy supplier. At the end of 2015, approximately 21 percent of all of PSNH’s customers (approximately 53 percent of load) were taking service from competitive energy suppliers, compared to 21 percent of customers (approximately 46 percent of load) at the end of 2014.

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. These charges recover the costs of PSNH’s generation, as well as purchased power, and include an allowed ROE of 9.81 percent.

- 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.

- A stranded cost recovery charge (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.



- A system benefits charge (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 energy charge and SCRC rates change semi-annually and are reconciled annually and differences between actual costs incurred versus current rates are either refunded or recovered in subsequent rates charged to customers.

PSNH distribution rates were set in a 2010 NHPUC rate case settlement, which expired on June 30, 2015. In the 2015 PSNH Settlement Agreement, the Company agreed that its present distribution rates will stay in effect until at least July 1, 2017. However, certain aspects of the 2010 rate case settlement will continue, including funding for reliability enhancement program activities, adjustment of distribution rates for certain exogenous events that in the aggregate exceed $1 million, and major storm reserve funding.

## Generation Divestiture

In 2013, the NHPUC opened a docket to investigate market conditions affecting PSNH’s default energy service rate, how PSNH will maintain just and reasonable rates in light of those conditions, and any impact of PSNH’s generation ownership on the New Hampshire competitive electric market. In April 2014, the NHPUC staff issued a “Preliminary Status Report Addressing the Economic Interest of PSNH’s Retail Customers as it Relates to the Potential Divestiture of PSNH’s Generating Plants,” which included a consultant’s analysis of the fair market value of PSNH generating assets and long-term power purchase contracts. The consultant’s analysis estimated the fair market value of PSNH’s generation assets to be $225 million as of December 31, 2013 and compared that amount to a stated net book value of $660 million, implying potential “stranded costs” of approximately $435 million. An abbreviated draft update by the consultant dated August 17, 2015, increased the estimated fair market value of PSNH’s generation assets to $235 million.

In 2014, the Legislature enacted changes to the laws governing divestiture of PSNH’s generation assets, effective September 30, 2014. The new law required the NHPUC to initiate a proceeding to determine whether all or some of PSNH’s generation assets should be divested. The law gives the NHPUC express authority to order the divestiture of all or some of PSNH’s generation assets if the NHPUC finds it is in the economic interest of customers to do so. The law also clarified the definition of “stranded costs” to include costs approved for recovery by the NHPUC in connection with the divestiture or retirement of PSNH’s generation assets.

On June 10, 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement (the Agreement) with the New Hampshire Office of Energy and Planning, certain members of the NHPUC staff, the Office of Consumer Advocate, two state senators, and several other parties. The Agreement was filed with the NHPUC on the same day. Under the terms of the Agreement, PSNH has agreed to divest its generation assets upon NHPUC approval. The Agreement is designed to provide a resolution of issues pertaining to PSNH’s generation assets in pending regulatory proceedings before the NHPUC. The Agreement provided for the Clean Air Project prudence proceeding to be resolved and all remaining Clean Air Project costs to be included in rates effective January 1, 2016. As part of the Agreement, PSNH has agreed to forego recovery of $25 million of the deferred equity return related to the Clean Air Project. In addition, PSNH will not seek a general distribution rate increase effective before July 1, 2017 and will contribute $5 million to create a clean energy fund, which will not be recoverable from its customers.

In 2015, the Legislature enacted changes to law to allow the use of securitization financing to recover any stranded costs resulting from the divestiture of PSNH’s generating assets. If the Agreement is approved, following divestiture of PSNH’s generating assets, bonds will be issued to recover resulting stranded costs.

On January 26, 2016, Advisory Staff of the NHPUC and the parties to the Agreement filed a stipulation with the NHPUC agreeing that near-term divestiture of PSNH’s generation was in the public interest and that the Agreement should be approved. Implementation of the Agreement is subject to NHPUC approval, which is expected in early 2016.

## Sources and Availability of Electric Power Supply

During 2015, approximately 54 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 46 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. PSNH expects to meet its load requirements in 2016 in a similar manner. Included in the 54 percent 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.

Merrimack and Schiller Stations have recently operated at lower than typical capacity factors due to moderate regional temperatures. The Hydro stations have been operating at high capacity factors. PSNH’s Energy Service Rate has been set at 9.99 cents per kWh effective January 1, 2016, which includes 1.27 cents per kWh reflecting full recovery of costs related to the Clean Air Project.

## ELECTRIC TRANSMISSION SEGMENT

## General

Each of CL&P, NSTAR Electric, PSNH and WMECO 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, PSNH and WMECO, 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 colspan="2">2015</td></tr><tr><td>CL&amp;P</td><td>$</td><td>513,025</td></tr><tr><td>NSTAR Electric</td><td></td><td>299,241</td></tr><tr><td>PSNH</td><td></td><td>127,509</td></tr><tr><td>WMECO</td><td></td><td>129,502</td></tr><tr><td>Total Wholesale Transmission Revenues</td><td>$</td><td>1,069,277</td></tr></table>

## Wholesale Transmission Rates

Wholesale transmission revenues are recovered through FERC approved formula rates. Transmission revenues are collected from New England customers, the majority of which are distribution customers of CL&P, NSTAR Electric, PSNH and WMECO. The transmission rates provide for the annual reconciliation 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

Three 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 (the “Complainants”). In these three separate complaints, the Complainants challenged the NETOs’ base ROE of 11.14 percent that had been utilized since 2006 and sought an order to reduce it prospectively from the date of the final FERC order and for the 15-month complaint refund periods stipulated in the separate complaints. In 2014, the FERC ordered a 10.57 percent base ROE for the first complaint refund period and prospectively from October 16, 2014 and that a utility’s total or maximum ROE shall not exceed the top of the new zone of reasonableness, which was set at 11.74 percent. The NETOs and the Complainants sought rehearing from the FERC. In late 2014, the NETOs made a compliance filing and the Company began issuing refunds to customers from the first complaint period.

On March 3, 2015, FERC issued an order denying all issues raised on rehearing by the NETOs and Complainants in the first complaint. The FERC order upheld the base ROE of 10.57 percent for the first complaint refund period and prospectively from October 16, 2014, and upheld that the utility’s total ROE (the base ROE plus any incentive adds) for the transmission assets to which the adder applies is capped at the top of the zone of reasonableness, which is currently set at 11.74 percent. The NETOs and Complainants have filed appeals to the D.C. Circuit Court of Appeals, which have been consolidated, and briefing is scheduled to be concluded in the second quarter of 2016. A court decision is expected in late 2016.

For the second and third complaint proceedings, hearings were held in late June and early July 2015 and briefs were filed in July and August 2015. The state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced to an amount lower than 10.57 percent. The NETOs believe that the Complainants’ positions are without merit, and the existing base ROE of 10.57 is just and reasonable and should be maintained. On December 18, 2015, the FERC ALJ reopened the record to have the NETOs and FERC trial staff review certain calculations. The FERC ALJ’s initial recommendation is expected by March 31, 2016. A final FERC order is expected in late 2016 or early 2017.

Although Eversource is uncertain on the final outcome of the second and third complaints regarding the ROE, we believe the current reserves established are appropriate to reflect probable and reasonably estimable refunds. 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.

## FERC Order No. 1000

On August 15, 2014, the D.C. Circuit Court of Appeals upheld the FERC’s authority to order major changes to transmission planning and cost allocation in FERC Order No. 1000 and Order No. 1000-A, including transmission planning for public policy needs, and the requirement that utilities remove from their transmission tariffs their rights of first refusal to build transmission. On March 19, 2015, the FERC acted on all rehearing requests filed by the NETOs, including CL&P, NSTAR Electric, PSNH and WMECO, and other parties and accepted the November 2013 compliance filing made by ISO-NE and the NETOs, subject to further compliance. The FERC accepted our proposal that the new competitive transmission planning process will not apply to certain projects, which have been declared as the preferred solution by ISO-NE, unless ISO-NE later decides a solution must be re-evaluated. The FERC determined on rehearing that we can restore provisions that recognize the NETOs’ rights to retain use and control of their existing rights of ways. Final compliance was filed by the NETOs in November 2015 and was accepted by the FERC on December 14, 2015.

Additionally, the FERC affirmed that it can eliminate our right of first refusal to build transmission in New England even though the FERC previously approved and granted special protections to these rights. The NETOs filed an appeal to the D.C. Circuit Court of Appeals, challenging this FERC ruling. State regulators also filed an appeal, challenging FERC’s determination that ISO-NE should select public policy transmission projects after a competitive process. The Court is expected to resolve the appeals in 2016.



## Transmission Projects

During 2015, we were involved in the planning, development and construction of a series of electric transmission projects, including the NEWS family of projects; the Greater Hartford Central Connecticut (GHCC) solutions; and Greater Boston Reliability Solutions, which are a series of new transmission projects over the next five years that will enhance system reliability and improve capacity. We were involved in the planning and development of Northern Pass, which is our planned 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; and the Clean Energy Connect Project, which is a planned transmission, wind and hydro generation project that we intend to develop with experienced renewable generation companies. 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

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 2015, our estimated transmission rate base was approximately $5.2 billion, including approximately $2.4 billion at CL&P, $1.4 billion at NSTAR Electric, $548 million at PSNH, and $625 million at WMECO.

## NATURAL GAS DISTRIBUTION SEGMENT

NSTAR Gas distributes natural gas to approximately 286,000 customers in 51 communities in central and eastern Massachusetts covering 1,067 square miles, and Yankee Gas distributes natural gas to approximately 226,000 customers in 71 cities and towns in Connecticut covering 2,187 square miles. Total throughput (sales and transportation) in 2015 was approximately 71.7 Bcf for NSTAR Gas and 57.8 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 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 2015 total Eversource Energy natural gas franchise retail revenues based on categories of customers:

<table><tr><td>(Thousands of Dollars, except percentages)</td><td>2015</td><td>% of Total</td></tr><tr><td>Residential</td><td>$ 497,873</td><td>54</td></tr><tr><td>Commercial</td><td>327,439</td><td>36</td></tr><tr><td>Industrial</td><td>93,378</td><td>10</td></tr><tr><td>Total Retail Natural Gas Revenues</td><td>$ 918,690</td><td>100%</td></tr></table>

A summary of our firm natural gas sales volumes in million cubic feet and percentage changes for 2015, as compared to 2014, is as follows:

<table><tr><td></td><td>2015</td><td>2014</td><td>Percentage Change</td></tr><tr><td>Residential</td><td>38,455</td><td>38,969</td><td>(1.3)%</td></tr><tr><td>Commercial</td><td>43,006</td><td>42,977</td><td>0.1 %</td></tr><tr><td>Industrial</td><td>21,538</td><td>22,245</td><td>(3.2)%</td></tr><tr><td>Total</td><td>102,999</td><td>104,191</td><td>(1.1)%</td></tr><tr><td>Total, Net of Special Contracts (1)</td><td>98,458</td><td>99,500</td><td>(1.0)%</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. In 2015, consolidated firm natural gas sales volumes were lower, as



compared to 2014. The 2015 firm natural gas sales volumes were negatively impacted by record warm weather in the fourth quarter of 2015, when compared to 2014, partially offset by colder winter weather in the first quarter of 2015, as compared to 2014, throughout our natural gas service territories. Weather-normalized Eversource consolidated firm natural gas sales volumes increased 2.5 percent in 2015, as compared to 2014, due primarily to improved economic conditions as well as residential and commercial customer growth, through conversions to natural gas service.

## 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. Both of Eversource Energy’s natural gas companies are entitled under their respective state law to charge rates that are sufficient to allow them an opportunity to recover their reasonable operating and capital costs, in order to attract needed capital and maintain their financial integrity, while also protecting relevant public interests.

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; and

- 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; and

- 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 NYMEX natural gas futures in order to reduce cash flow variability associated with the purchase price for approximately one-third of its natural gas purchases. 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 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 distribution revenues for failing to meet such metrics. NSTAR Gas will not be required to pay a SQ charge for its 2015 performance as it achieved results at or above target for all of its SQ metrics in 2015.

On October 30, 2015, the DPU issued its order in the NSTAR Gas distribution rate case, which approved 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. On November 19, 2015, NSTAR Gas filed a motion for reconsideration of the order with the DPU seeking the correction of mathematical errors and other plant and cost of service items.

Yankee Gas’ last rate 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.



## Massachusetts Natural Gas Replacement and Expansion

On July 7, 2014, Massachusetts enacted “An Act Relative to Natural Gas Leaks” (the Act). The Act establishes 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 will enable companies, including NSTAR Gas, to better manage the scheduling and costs of replacement. The Act also calls 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 $255 million for the period 2016 through 2019 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 (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 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 March 20, 2015, Yankee Gas filed its initial System Expansion (SE) Rate reconciliation for 2014. The proposed SE rate was approved by the PURA for implementation as of April 1, 2015, pending final PURA approval following a contested hearing.

## 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 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, which has a maximum quantity of approximately 154,700 MMBtu/day of firm flowing natural gas supplies and 76,700 MMBtu/day of firm natural gas storage supplies.

In addition to the firm transportation and natural gas 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. Yankee Gas has long-term firm contracts for capacity on TransCanada Pipelines Limited Pipeline, Vector Pipeline, L.P., Tennessee Gas Pipeline, Iroquois Gas Transmission Pipeline, Algonquin Pipeline, Union Gas Limited, Dominion Transmission, Inc., National Fuel Gas Supply Corporation, Transcontinental Gas Pipeline Company, and Texas Eastern Transmission, L.P. pipelines.

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.

## NATURAL GAS PIPELINE EXPANSION

Access Northeast is a natural gas pipeline and storage project (the “Project”) being developed jointly by Eversource, Spectra Energy Corp and National Grid. Access Northeast will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes and will include two new LNG storage tanks and liquefaction and vaporization facilities in Acushnet, Massachusetts that will be connected to the Algonquin gas pipeline. The Project is expected to be capable of delivering approximately 900 million cubic feet of additional natural gas per day to New England on peak demand days. Eversource and Spectra Energy Corp each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid. The total projected cost for both the pipeline and the LNG storage is expected to be approximately $3 billion with anticipated in-service dates commencing in November 2018. The Project is subject to FERC and other federal and state regulatory approvals. On November 17,



2015, the FERC accepted the Project’s request to initiate the pre-filing review process. Upon completion of the pre-filing review, a certificate application will be filed with the FERC. In late 2015, the Project bid into the New England Natural Gas Pipeline Capacity RFP conducted by certain EDCs in Massachusetts and Rhode Island, including NSTAR Electric and WMECO in Massachusetts, and in December 2015 and January 2016, those Massachusetts EDCs filed with the DPU seeking approval of the contracts for pipeline and storage capacity with the Project. We expect the Rhode Island EDC to file its selected contracts with the Rhode Island regulatory agencies in the first half of 2016. In February 2016, PSNH filed for approval with the NHPUC, of its proposed contract for natural gas pipeline capacity and storage with the Project.

## PROJECTED CAPITAL EXPENDITURES

We project to make capital expenditures of approximately $9.2 billion from 2016 through 2019. Of the $9.2 billion, we expect to invest approximately $4.9 billion in our electric and natural gas distribution segments and $3.9 billion in our electric transmission segment. In addition, we project to invest approximately $0.4 billion in information technology and facilities upgrades and enhancements. These projections do not include capital expenditures related to Access Northeast or Clean Energy Connect.

## FINANCING

Our credit facilities and indentures require that Eversource Energy parent and certain of its subsidiaries, including CL&P, NSTAR Electric, NSTAR Gas, PSNH, WMECO and Yankee Gas, 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, 2015, a total of $200 million of Eversource’s long-term debt, all at NSTAR Electric, will be paid in the next 12 months.

## NUCLEAR FUEL STORAGE

CL&P, NSTAR Electric, PSNH, WMECO 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, PSNH and WMECO and several other New England utilities. The decommissioning rates charged by the Yankee Companies have been reduced to zero. CL&P, NSTAR Electric, PSNH and WMECO 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.

For information on the DOE proceeds received related to the spent nuclear fuel litigation, see Note 11C, “Commitments and Contingencies – Contractual Obligations – Yankee Companies,” in the accompanying Item 8, Financial Statements and Supplementary Data.

## 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 and Yankee Gas, the NHPUC, which has jurisdiction over PSNH, and the DPU, which has jurisdiction over NSTAR Electric, NSTAR Gas and WMECO.

## 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. We are in the process of maintaining or renewing all required NPDES or state discharge permits in effect for PSNH’s generation facilities.

In 1997, PSNH filed in a timely manner for a renewal of the NPDES permit for the Merrimack Station. As a result, the existing permit was administratively continued. In 2011, the EPA issued a draft renewal NPDES permit for PSNH’s Merrimack Station for public review and comment. The proposed permit contains many significant conditions to future operation. The proposed permit would require PSNH to install a closed-cycle cooling system (including cooling towers) at the station. The EPA estimated that the net present value cost to install this system and operate it over a



20-year period would be approximately $112 million. PSNH and other electric utility groups filed thousands of pages of comments contesting EPA’s draft permit requirements. PSNH stated that the data and studies supplied to the EPA demonstrate the fact that a closed-cycle cooling system is not warranted. On April 18, 2015 EPA issued a revised section of the draft NPDES permit for Merrimack Station. The revised portion of the draft permit deals solely with the treatment of wastewater from the flue gas desulfurization system. On August 18, 2015 PSNH again submitted comments. The EPA does not have a set deadline to consider comments and to issue a final permit. Merrimack Station is permitted to continue to operate under its present permit pending issuance of the final permit and subsequent resolution of matters appealed by PSNH and other parties. Due to the site specific characteristics of PSNH’s other coal- and oil-fired electric generating stations, we believe it is unlikely that they would face similar permitting determinations.

## 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.

In 2011, the EPA finalized the Mercury and Air Toxic Standards (MATS) that require the reduction of emissions of hazardous air pollutants from new and existing coal- and oil-fired electric generating stations. Previously referred to as the Utility MACT (maximum achievable control technology) rules, it establishes emission limits for mercury, arsenic and other hazardous air pollutants from coal- and oil-fired electric generating stations. MATS is the first implementation of a nationwide emissions standard for hazardous air pollutants across all electric generating units and provides utility companies with up to five years to meet the requirements. PSNH owns and operates approximately 1,000 MW of coal- and oil-fired electric generating stations subject to MATS, including the two units at Merrimack Station, Newington Station and the two coal units at Schiller Station. We believe the Clean Air Project at our Merrimack Station, together with existing equipment, will enable the facility to meet the MATS requirements. At Schiller Station additional controls are being installed at the two coal-fired units, the cost of which is estimated to be approximately $2.5 million.

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, 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 2015, the total RPS obligation was 8.3 percent and it will ultimately reach 24.8 percent in 2025. Energy suppliers, like PSNH, must possess sufficient quantities of RECs to satisfy the RPS requirements. PSNH owns renewable sources and uses a portion of internally generated RECs to meet its RPS obligations and sells other internally generated RECs when it is economically beneficial to do so. To the extent that a supplier, like PSNH, does not possess sufficient RECs to satisfy its RPS requirements, it makes up any shortfall by making an alternative compliance payment at a rate per REC established by law. The costs of both the RECs and alternative compliance payments are recovered by PSNH through its default energy service 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 2015, the total RPS obligation was 19.5 percent and will ultimately reach 27 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 2015, the requirement was 19.25 percent, and will ultimately reach 22.1 percent in 2020. NSTAR Electric and WMECO are permitted to recover any costs incurred in complying with RPS from its customers through rates. WMECO also owns renewable solar generation resources. The RECs generated from WMECO’s solar units 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, 2015, 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 approximately $51.1 million, representing 64 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 $45.5 million of the total $51.1 million as of December 31, 2015. Many of these MGP costs are recoverable from customers through our rates.

## 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  \( SF_{6} \)  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 extends 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.

PSNH anticipates that its generating units will emit between one million and three million tons of  \( CO_{2} \)  per year, depending on the capacity factor and the utilization of the respective generation plant, excluding emissions from the operation of PSNH's Northern Wood Power Project, which emissions are an offset. PSNH satisfied its RGGI requirements by purchasing  \( CO_{2} \)  allowances at auction. The cost of complying with RGGI requirements is recoverable from PSNH customers. Current legislation provides that the portion of the RGGI auction proceeds in excess of 1 per allowance will be refunded to customers.

Because none of Eversource Energy’s other subsidiaries, CL&P, NSTAR Electric or WMECO, currently owns any generating assets (other than WMECO’s solar photovoltaic facilities that do not emit  \( CO_{2} \) ), none of them is required to acquire  \( CO_{2} \)  allowances. However, the  \( CO_{2} \)  allowance costs borne by the generating facilities that are utilized by wholesale energy suppliers to satisfy energy supply requirements to CL&P, NSTAR Electric and WMECO are likely to be included in the overall wholesale rates charged, which costs are then recoverable from customers.

## 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 generating stations with a current claimed capability representing winter rates of approximately 71 MW, eight of which are licensed by the FERC under long-term licenses that expire on varying dates from 2017 through 2047. PSNH and its hydroelectric projects 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. PSNH is currently completing the relicensing application for its 6.5 MW Eastman Falls Hydro Station, the license for which expires in 2017.

## EMPLOYEES

As of December 31, 2015, Eversource Energy employed a total of 7,943 employees, excluding temporary employees, of which 1,037 were employed by CL&P, 1,240 were employed by NSTAR Electric, 694 were employed by PSNH, and 291 were employed by WMECO. 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 14 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, PSNH’s and WMECO’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.

Cyber breaches, acts of war or terrorism, or grid disturbances could negatively impact our business.

Cyber breaches, acts of war or terrorism, physical attacks or grid disturbances resulting from internal or external sources could target our transmission, distribution and generation facilities or our information technology systems. Such actions could impair our ability to manage these facilities, operate our systems effectively, or properly manage our data, networks and programs, resulting in loss of service to customers.

We have instituted safeguards to protect our operational systems and information technology 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. FERC, through the North American Electric Reliability Corporation, requires certain safeguards to be implemented to deter cyber and/or physical attacks. These safeguards may not always be effective due to the evolving nature of cyber and/or physical attacks.

Because our generation and transmission facilities are part of an interconnected regional grid, we face the risk of blackout due to a disruption on a neighboring interconnected system.

Any such cyber breaches, acts of war or terrorism, physical attacks or grid disturbances could result in a significant decrease in revenues, significant expense to repair system damage or security breaches, and liability claims, which could have a material adverse impact on our financial position, results of operations or cash flows.

Strategic development opportunities in both electric and natural gas transmission 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 and natural gas transmission facilities, interconnections to generating resources and other investment opportunities. The development, construction and expansion of electric transmission and natural gas transmission facilities involve 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 during 2015, the states in which we provide service have implemented new procedures to select for construction new major electric transmission and gas pipeline 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, it would have a material adverse effect on our future financial position, results of operations and cash flows.

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

The rates that our electric and gas companies charge their customers are determined by their state regulatory commissions and by FERC. These commissions also regulate the companies' accounting, operations, the issuance of certain securities and certain other matters. 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 and gas companies are entitled to charge rates that are sufficient to allow them an opportunity to recover their reasonable operating and capital costs, 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 the allowed return on equity. The ROE has been contested by outside parties as unjust and unreasonable. Certain outside parties have filed three complaints against all electric companies under the jurisdiction of ISO-NE alleging that the ROE is unjust and unreasonable. The first complaint, which was concluded in 2015, resulted in a decrease of the allowed ROE. The second and third complaints are currently under review with the FERC. The FERC has initiated a review of the regional and local transmission rates due to a lack of adequate transparency. FERC also found that the formula rates generally lacked sufficient details to determine how costs are derived and recovered in rates.

A federal appeals court decision has upheld the FERC’s authority to order major changes to transmission planning and cost allocation in FERC Order No. 1000 and Order No. 1000-A, including transmission planning for public policy needs, and the requirement that utilities remove from their transmission tariffs their rights of first refusal to build transmission. Additionally, the FERC affirmed that it can eliminate our right of first refusal to build transmission in New England even though the FERC previously approved and granted special protections to these rights. Implementation of FERC’s goals in New England, 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 and gas 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.

If our settlement agreement regarding the divestiture of our generation assets in New Hampshire is not approved, it could have a material adverse effect on our earnings.

Under our settlement agreement for the divestiture of our generation assets in New Hampshire, we will be entitled to collect from customers an amount equal to the difference between the proceeds from the sale of these assets and the undepreciated book value of those assets. Costs related to the divestiture would also be recoverable. To minimize the financial impact on customers in New Hampshire, the legislature passed legislation that allows for the securitization of stranded costs to be recovered. If the NHPUC does not approve the settlement, we may not be able to fully recover these costs in future rate proceedings, which could have a material adverse effect on our financial position, results of operations and cash flows.

Our transmission, distribution and generation 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, distribution and generation systems is critical to the financial performance of our business. Our transmission, distribution and generation 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 and natural gas, 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, distribution and generation systems to operate as planned may result in increased capital costs, reduced earnings or unplanned increases in operation and maintenance costs. Outages at generating stations may be deemed imprudent by the NHPUC resulting in disallowance of replacement power and repair costs. Such costs that are not recoverable from our customers would have an adverse effect on our financial position, results of operations and cash flows.

Increases in electric and gas prices and/or a weak economy can lead to changes in legislative and regulatory policy promoting increased energy efficiency, conservation, and self-generation and/or a reduction in our customers' ability to pay their bills, which may adversely impact our business.

Energy consumption is significantly impacted by the general level of economic activity and cost of energy supply. 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. This focus on conservation, energy efficiency and self-generation may result in a decline in electricity and natural gas sales in our service territories. Economic downturns or periods of high energy supply costs can also impact customers' ability to pay their energy bills, resulting in increased bad debt expense. If energy use were to decline or bad debt expense were to increase, without corresponding adjustments in rates at our electric and gas companies that do not currently have revenue decoupling, then our revenues would be reduced, which would have an adverse effect on our financial position, results of operations and cash flows.

Severe storms could cause significant damage to any of our facilities requiring extensive expenditures, the recovery for which is subject to approval by regulators.

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 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. As of December 31, 2015, goodwill totaled $3.5 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 2015 resulted in a conclusion that our goodwill is 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 and natural gas 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 Eversource Energy and its subsidiaries in a favorable light; and may cause Eversource Energy and its subsidiaries 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, results of operations, cash flow and financial condition 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.

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 cyber crime 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 cyber-attacks and mitigate their effects should they occur. These measures may not be effective due to the continually evolving nature of efforts to access confidential information.

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, including many workers with specialized skills maintaining and servicing the electrical 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.

Market performance or changes in assumptions 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.

Costs of compliance with environmental regulations, including climate change legislation, 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 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.

In addition, global climate change issues have received an increased focus from federal and state government agencies. Although we would expect that any costs of these rules and regulations would be recovered from customers, their impact on energy use by customers and the ultimate impact on our business would be dependent upon the specific rules and regulations adopted and cannot be determined at this time. The impact of these additional costs to customers could lead to a further reduction in energy consumption resulting in a decline in electricity and gas sales in our service territories, which would have an adverse impact on our business and financial position, results of operations or cash flows. Any failure by us to comply with environmental laws and regulations, even if due to factors beyond our control, or reinterpreations of existing requirements, could also increase costs. Existing environmental laws and regulations may be revised or new laws and regulations seeking to protect the environment may be adopted or become applicable to us. Revised or additional laws could result in significant additional expense and operating restrictions on our facilities or increased compliance costs, which may not be fully recoverable in distribution company rates. The cost impact of any such laws, rules or regulations would be dependent upon the specific requirements adopted and cannot be determined at this time. For further information, see Item 1, Business - Other Regulatory and Environmental Matters, included in this Annual Report on Form 10-K.

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, 2015, 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>512</td><td>66</td></tr><tr><td>Transformer capacity (in kVa)</td><td>41,484,000</td><td>13,780,000</td></tr><tr><td>Overhead lines (in circuit miles)</td><td>40,258</td><td>3,932</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>16,778</td><td>407</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><td colspan="2">WMECO</td></tr><tr><td>Distribution</td><td>Transmission</td><td>Distribution</td><td>Transmission</td><td>Distribution</td><td>Transmission</td><td>Distribution</td><td>Transmision</td></tr><tr><td>Number of substations owned</td><td>182</td><td>19</td><td>133</td><td>24</td><td>154</td><td>16</td><td>43</td><td>7</td></tr><tr><td>Transformer capacity (in kVa)</td><td>19,605,000</td><td>3,117,000</td><td>11,431,000</td><td>6,728,000</td><td>5,257,000</td><td>3,868,000</td><td>5,191,000</td><td>67,000</td></tr><tr><td>Overhead lines (in circuit miles)</td><td>16,951</td><td>1,662</td><td>7,983</td><td>750</td><td>11,913</td><td>1,039</td><td>3,411</td><td>481</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>115 to 345</td><td>N/A</td><td>115 to 345</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>6,528</td><td>136</td><td>7,354</td><td>260</td><td>1,821</td><td>1</td><td>1,075</td><td>10</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><td>N/A</td><td>115</td></tr><tr><td></td><td></td><td></td><td></td><td></td><td>NSTAR</td><td></td><td></td><td></td></tr><tr><td></td><td></td><td></td><td></td><td></td><td>Electric</td><td>PSNH</td><td>WMECO</td><td></td></tr><tr><td>Underground and overhead line transformers in service</td><td></td><td>618,387</td><td>288,352</td><td>126,353</td><td>160,848</td><td>42,834</td><td></td><td></td></tr><tr><td>Aggregate capacity (in kVa)</td><td></td><td>35,097,967</td><td>15,300,765</td><td>11,429,921</td><td>6,202,270</td><td>2,165,011</td><td></td><td></td></tr></table>

## Electric Generating Plants

As of December 31, 2015, 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>935,343</td></tr><tr><td>Hydro</td><td>20</td><td>1901-83</td><td>58,115</td></tr><tr><td>Internal Combustion</td><td>5</td><td>1968-70</td><td>101,869</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>1,137,921</td></tr></table>

* Claimed capability represents winter ratings as of December 31, 2015. The combined nameplate capacity of the generating plants is approximately 1,200 MW.

As of December 31, 2015, WMECO owned the following electric generating plants:

<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 and NSTAR Electric do not own any electric generating plants.

## Natural Gas Distribution System

As of December 31, 2015, Yankee Gas owned 28 active gate stations, 203 district regulator stations, and approximately 3,317 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, 2015, NSTAR Gas owned 21 active gate stations, 164 district regulator stations, and approximately 3,250 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.

## 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 Energy Independence,” enacted in 2005, CL&P is permitted to own up to 200 MW of peaking facilities if the PURA determines that such facilities will be more cost effective than other options for mitigating FMCC and Locational Installed Capacity (LICAP) costs. In addition, 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. Finally, Connecticut law also allows CL&P to submit a proposal to the DEEP to build, own or operate one or more generation facilities up to 10 MWs using Class I renewable energy.

NSTAR Electric and NSTAR Gas Through their charters, which are unlimited in time, NSTAR Electric and NSTAR Gas have the right to engage in the business of delivering and selling electricity and natural gas within their respective service territories, and have powers incidental thereto and are entitled to all the rights and privileges of and subject to the duties imposed upon electric and natural gas companies under Massachusetts laws. The locations in public ways for electric transmission and distribution lines and 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 electric or natural gas delivery service to retail customers within NSTAR's service territory without the written consent of NSTAR Electric and/or NSTAR Gas. This consent must be filed with the DPU and the municipality so affected.

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 its transmission and distribution services in appropriate circumstances.

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

WMECO WMECO is authorized by its charter to conduct its electric business in the territories served by it, and has locations in the public highways for transmission and distribution lines. Such locations are granted pursuant to the laws of Massachusetts by the Department of Public Works of Massachusetts or local municipal authorities and are of unlimited duration, but the rights thereby granted are not vested. Such locations are for specific lines only and for extensions of lines in public highways. Further similar locations must be obtained from the Department of Public Works of Massachusetts or the local municipal authorities. In addition, WMECO has been granted easements for its lines in the Massachusetts Turnpike by the Massachusetts Turnpike Authority and pursuant to state laws, has the power of eminent domain.

The Massachusetts restructuring legislation applicable to NSTAR Electric (described above) is also applicable to WMECO.

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. 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.

## Item 3. Legal Proceedings

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

DOE Phase I Damages - In 1998, the Yankee Companies (CYAPC, YAEC and MYAPC) 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 period 1998 through 2002. Following multiple appeals and cross-appeals in December 2012, the judgment awarding CYAPC $39.6 million, YAEC $38.3 million and MYAPC $81.7 million 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, PSNH and WMECO 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’s three-year refund plan, MYAPC returned a portion of the DOE Phase I Damages proceeds to the member companies, including CL&P, NSTAR Electric, PSNH, and WMECO, in the amount of $3.2 million, $1.1 million, $1.4 million and $0.8 million, respectively. On September 28, 2015, MYAPC returned the remaining DOE Phase I Damages proceeds to the member companies, including CL&P, NSTAR Electric, PSNH, and WMECO, in the amount of $2.3 million, $0.8 million, $1 million and $0.6 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 CYAPC $126.3 million, YAEC $73.3 million, and MYAPC $35.8 million. 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, PSNH, and WMECO, for the benefit of their respective customers, on June 1, 2014. Refunds to CL&P's, NSTAR Electric's, PSNH's and WMECO'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. The trial on this matter was held on June 30 and July 1, 2015, with a post-trial briefing that concluded on October 14, 2015. The parties are awaiting a decision from the court.

## 2. Conservation Law Foundation v. PSNH

On July 21, 2011, the Conservation Law Foundation (CLF) filed a citizens suit under the provisions of the federal Clean Air Act against PSNH alleging permitting violations at the company’s Merrimack generating station. The suit alleges that PSNH failed to have proper permits for replacement of the Unit 2 turbine at Merrimack, installation of activated carbon injection equipment for the unit, and violated a permit condition concerning operation of the electrostatic precipitators at the station. On September 27, 2012, the federal court dismissed portions of CLF’s suit pertaining to the installation of activated carbon injection and the electrostatic precipitators. CLF filed an amended complaint on May 28, 2013, related to routine maintenance of the boiler performed in 2008 and 2009. The suit seeks injunctive relief, civil penalties, and costs. CLF has pursued similar claims before the NHPUC, the N.H. Air Resources Council, and the N.H. Site Evaluation Committee, all of which have been denied. PSNH continues to believe this suit is without merit and intends to defend it vigorously. However, at this time the case has been stayed while the State settlement process related to the divestiture of generating assets, including Merrimack Station, continues.

## 3. 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 high-level nuclear waste; and “- Other Regulatory and Environmental Matters” for information about proceedings involving surface water and air quality requirements, toxic substances and hazardous waste, electric and magnetic fields, licensing of hydroelectric projects, 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 16, 2016. 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>Thomas J. May</td><td>68</td><td>Chairman of the Board, President and Chief Executive Officer</td></tr><tr><td>James J. Judge</td><td>60</td><td>Executive Vice President and Chief Financial Officer</td></tr><tr><td>Leon J. Olivier</td><td>67</td><td>Executive Vice President-Enterprise Energy Strategy and Business Development</td></tr><tr><td>David R. McHale</td><td>55</td><td>Executive Vice President and Chief Administrative Officer</td></tr><tr><td>Werner J. Schweiger</td><td>56</td><td>Executive Vice President and Chief Operating Officer</td></tr><tr><td>Gregory B. Butler</td><td>58</td><td>Senior Vice President and General Counsel</td></tr><tr><td>Christine M. Carmody*</td><td>53</td><td>Senior Vice President-Human Resources of Eversource Service</td></tr><tr><td>Joseph R. Nolan, Jr.*</td><td>52</td><td>Senior Vice President-Corporate Relations of Eversource Service</td></tr><tr><td>Jay S. Buth</td><td>46</td><td>Vice President, Controller and Chief Accounting Officer</td></tr></table>



 \( ^{*} \) Deemed an executive officer of Eversource Energy pursuant to Rule 3b-7 under the Securities Exchange Act of 1934.

Thomas J. May. Mr. May has served as Chairman of the Board of Eversource Energy since October 10, 2013, and as President and Chief Executive Officer and as a Trustee of Eversource Energy; as Chairman and a Director of CL&P, NSTAR Electric, NSTAR Gas, PSNH, WMECO and Yankee Gas; and as Chairman, President and Chief Executive Officer and a Director of Eversource Service since April 10, 2012. Mr. May has served as a Director of NSTAR Electric and NSTAR Gas since September 27, 1999. Mr. May previously served as Chairman, President and Chief Executive Officer and a Trustee of NSTAR, and as Chairman, President and Chief Executive Officer of NSTAR Electric and NSTAR Gas until April 10, 2012. He served as Chairman, Chief Executive Officer and a Trustee since NSTAR was formed in 1999, and was elected President in 2002. Mr. May has served as Chairman of the Board of Eversource Energy Foundation, Inc. since October 15, 2013, and as a Director of Eversource Energy Foundation, Inc. since April 10, 2012. He previously served as President of Eversource Energy Foundation, Inc. from October 15, 2013 to September 29, 2014. He has served as a Trustee of the NSTAR Foundation since August 18, 1987.

James J. Judge. Mr. Judge has served as Executive Vice President and Chief Financial Officer of Eversource Energy, CL&P, NSTAR Electric, NSTAR Gas, PSNH, WMECO, Yankee Gas and Eversource Service and as a Director of CL&P, PSNH, WMECO, 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 Senior Vice President and Chief Financial Officer of NSTAR, NSTAR Electric and NSTAR Gas from 1999 until April 2012. Mr. Judge has served as Treasurer and as a Director of Eversource Energy Foundation, Inc. since April 10, 2012. He has served as a Trustee of the NSTAR Foundation since December 12, 1995.

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 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 and Eversource Service from May 13, 2008 until September 2, 2014, and 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 to September 29, 2014, and of CL&P from September 10, 2001 to September 29, 2014, and as a Director of NSTAR Electric and NSTAR Gas from November 27, 2012 to September 29, 2014, of PSNH, WMECO and Yankee Gas from January 17, 2005 to September 29, 2014, and of CL&P from September 10, 2001 to September 29, 2014. Previously, Mr. Olivier served as Executive Vice President-Operations of Eversource Energy from February 13, 2007 to May 12, 2008. 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.

David R. McHale. Mr. McHale has served as Executive Vice President and Chief Administrative Officer of Eversource Energy and Eversource Service since April 10, 2012 and as a Director of Eversource Service since January 1, 2005. Mr. McHale previously served as Executive Vice President and Chief Administrative Officer of CL&P, NSTAR Electric, NSTAR Gas, PSNH, WMECO and Yankee Gas from April 10, 2012 to September 29, 2014 and as a Director of NSTAR Electric and NSTAR Gas from November 27, 2012 to September 29, 2014, of PSNH, WMECO and Yankee Gas from January 1, 2005 to September 29, 2014, and of CL&P from January 15, 2007 to September 29, 2014. Previously, Mr. McHale served as Executive Vice President and Chief Financial Officer of Eversource Energy, CL&P, PSNH, WMECO, Yankee Gas and Eversource Service from January 2009 to April 2012, and as Senior Vice President and Chief Financial Officer of Eversource Energy, CL&P, PSNH, WMECO, Yankee Gas and Eversource Service from January 2005 to December 2008. He has served as a Director of Eversource Energy Foundation, Inc. since January 1, 2005. Mr. McHale 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 and of Eversource Service since August 11, 2014, and as President of CL&P since June 2, 2015 and as Chief Executive Officer of CL&P, NSTAR Electric, NSTAR Gas, PSNH, WMECO and Yankee Gas since August 11, 2014, and as a Director of Eversource Service, NSTAR Gas and Yankee Gas since September 29, 2014 and of CL&P, PSNH, NSTAR Electric and WMECO since May 28, 2013. He previously served as President-Electric Distribution of Eversource Service from January 16, 2013 until August 11, 2014 and as President of NSTAR Electric from April 10, 2012 until January 16, 2013 and as a Director of NSTAR Electric from November 27, 2012 to January 16, 2013. From February 27, 2002 until April 10, 2012, Mr. Schweiger was Senior Vice President-Operations of NSTAR Electric and NSTAR Gas. 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.

Gregory B. Butler. Mr. Butler has served as Senior Vice President and General Counsel of Eversource Energy since May 1, 2014, of NSTAR Electric, and NSTAR Gas since April 10, 2012, and of CL&P, PSNH, WMECO, Yankee Gas and Eversource Service since March 9, 2006. 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, WMECO and Yankee Gas since April 22, 2009. Mr. Butler previously served as Senior Vice President, General Counsel and Secretary of Eversource Energy from April 10, 2012 until May 1, 2014, and as Senior Vice President and General Counsel of Eversource Energy from December 1, 2005 to April 10, 2012. 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 Senior Vice President-Human Resources of Eversource Service since April 10, 2012 and as a Director of Eversource Service since November 27, 2012. Ms. Carmody previously served as Senior Vice President-Human Resources of CL&P, PSNH, WMECO and Yankee Gas from November 27, 2012 to September 29, 2014, and of NSTAR Electric and NSTAR Gas from August 1, 2008 to September 29, 2014, and as a Director of CL&P, PSNH, WMECO and Yankee Gas from April 10, 2012 to September 29, 2014 and of NSTAR Electric and NSTAR Gas from November 27, 2012 to September 29, 2014. Previously, Ms. Carmody served as Vice President-Organizational Effectiveness of NSTAR, NSTAR Electric and NSTAR Gas from June 2006 to August 2008. 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 Senior Vice President-Corporate Relations of Eversource Service since April 10, 2012 and as a Director of Eversource Service since November 27, 2012. Mr. Nolan previously served as Senior Vice President-Corporate Relations of NSTAR Electric and NSTAR Gas from April 10, 2012 to September 29, 2014, and of CL&P, PSNH, WMECO and Yankee Gas from November 27, 2012 to



September 29, 2014, as a Director of CL&P, PSNH, WMECO and Yankee Gas from April 10, 2012 to September 29, 2014 and of NSTAR Electric and NSTAR Gas from November 27, 2012 to September 29, 2014. Previously, Mr. Nolan served as Senior Vice President-Customer & Corporate Relations of NSTAR, NSTAR Electric and NSTAR Gas from 2006 until April 10, 2012. Mr. Nolan has served as a Director of Eversource Energy Foundation, Inc. since April 10, 2012, and has served 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.

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, WMECO, Yankee Gas and Eversource Service since April 10, 2012. Previously, Mr. Buth served as Vice President-Accounting and Controller of Eversource Energy, CL&P, PSNH, WMECO, Yankee Gas and Eversource Service from June 2009 until April 10, 2012. From June 2006 through January 2009, Mr. Buth served as the Vice President and Controller for New Jersey Resources Corporation, an energy services holding company that provides natural gas and wholesale energy services, including transportation, distribution and asset management.

## 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">2015</td><td>First</td><td>$ 56.83</td><td>$ 48.54</td><td>$ 0.4175</td></tr><tr><td>Second</td><td>51.42</td><td>45.20</td><td>0.4175</td></tr><tr><td>Third</td><td>52.15</td><td>44.64</td><td>0.4175</td></tr><tr><td>Fourth</td><td>52.85</td><td>48.18</td><td>0.4175</td></tr><tr><td rowspan="4">2014</td><td>First</td><td>$ 45.69</td><td>$ 41.28</td><td>$ 0.3925</td></tr><tr><td>Second</td><td>47.60</td><td>44.28</td><td>0.3925</td></tr><tr><td>Third</td><td>47.37</td><td>41.92</td><td>0.3925</td></tr><tr><td>Fourth</td><td>56.66</td><td>44.37</td><td>0.3925</td></tr></table>

Information with respect to dividend restrictions for us, CL&P, NSTAR Electric, PSNH, and WMECO is contained in Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations, under the caption “Liquidity” and 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, PSNH and WMECO. All of the common stock of CL&P, NSTAR Electric, PSNH and WMECO 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>2015</td><td>2014</td></tr><tr><td>CL&amp;P</td><td>$</td><td>196.0</td></tr><tr><td>NSTAR Electric</td><td></td><td>198.0</td></tr><tr><td>PSNH</td><td></td><td>106.0</td></tr><tr><td>WMECO</td><td></td><td>37.2</td></tr></table>

(b) Holders

As of January 31, 2016, there were 42,493 registered common shareholders of our company on record. As of the same date, there were a total of 317,191,249 common 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 2010 in Eversource Energy common stock, as compared with the S&P 500 Stock Index and the EEI Index for the period 2011 through 2015, assuming all dividends are reinvested.

## Total Shareholder Return



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, 2015</td><td>117,887</td><td>50.33</td><td>-</td><td>-</td></tr><tr><td>November 1 - November 30, 2015</td><td>3,178</td><td>50.76</td><td>-</td><td>-</td></tr><tr><td>December 1 - December 31, 2015</td><td>6,001</td><td>51.17</td><td>-</td><td>-</td></tr><tr><td>Total</td><td>127,066</td><td>50.38</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>2015</td><td>2014</td><td>2013</td><td>2012 (a)</td><td>2011</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>$ 19,892,441</td><td>$ 18,647,041</td><td>$ 17,576,186</td><td>$ 16,605,010</td><td>$ 10,403,065</td></tr><tr><td>Total Assets (b)</td><td>30,580,309</td><td>29,740,387</td><td>27,760,315</td><td>28,269,780</td><td>15,617,627</td></tr><tr><td>Total Capitalization (b) (c) (d)</td><td>19,542,240</td><td>18,946,395</td><td>18,042,052</td><td>17,323,068</td><td>9,048,882</td></tr><tr><td>Obligations Under Capital Leases (c)</td><td>8,222</td><td>9,434</td><td>10,744</td><td>11,071</td><td>12,358</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>$ 7,954,827</td><td>$ 7,741,856</td><td>$ 7,301,204</td><td>$ 6,273,787</td><td>$ 4,465,657</td></tr><tr><td>Net Income</td><td>886,004</td><td>827,065</td><td>793,689</td><td>533,077</td><td>400,513</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>7,519</td><td>7,519</td><td>7,682</td><td>7,132</td><td>5,820</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 878,485</td><td>$ 819,546</td><td>$ 786,007</td><td>$ 525,945</td><td>$ 394,693</td></tr><tr><td>Common Share Data:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Earnings Per Common Share</td><td>$ 2.77</td><td>$ 2.59</td><td>$ 2.49</td><td>$ 1.90</td><td>$ 2.22</td></tr><tr><td>Diluted Earnings Per Common Share</td><td>$ 2.76</td><td>$ 2.58</td><td>$ 2.49</td><td>$ 1.89</td><td>$ 2.22</td></tr><tr><td>Weighted Average Common Shares Outstanding:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Basic</td><td>317,336,881</td><td>316,136,748</td><td>315,311,387</td><td>277,209,819</td><td>177,410,167</td></tr><tr><td>Diluted</td><td>318,432,687</td><td>317,417,414</td><td>316,211,160</td><td>277,993,631</td><td>177,804,568</td></tr><tr><td>Dividends Declared Per Common Share</td><td>$ 1.67</td><td>$ 1.57</td><td>$ 1.47</td><td>$ 1.32</td><td>$ 1.10</td></tr><tr><td>Market Price - Closing (high) (c)</td><td>$ 54.52</td><td>$ 56.15</td><td>$ 45.33</td><td>$ 40.57</td><td>$ 36.31</td></tr><tr><td>Market Price - Closing (low) (c)</td><td>$ 44.63</td><td>$ 41.52</td><td>$ 38.67</td><td>$ 33.53</td><td>$ 30.46</td></tr><tr><td>Market Price - Closing (end of year) (c)</td><td>$ 51.07</td><td>$ 53.52</td><td>$ 42.39</td><td>$ 39.08</td><td>$ 36.07</td></tr><tr><td>Book Value Per Common Share (end of year)</td><td>$ 32.64</td><td>$ 31.47</td><td>$ 30.49</td><td>$ 29.41</td><td>$ 22.65</td></tr><tr><td>Tangible Book Value Per Common Share (end of year) (f)</td><td>$ 21.54</td><td>$ 20.37</td><td>$ 19.32</td><td>$ 18.21</td><td>$ 21.03</td></tr><tr><td>Rate of Return Earned on Average Common Equity (%) (g)</td><td>8.7</td><td>8.4</td><td>8.3</td><td>7.9</td><td>10.1</td></tr><tr><td>Market-to-Book Ratio (end of year) (h)</td><td>1.6</td><td>1.7</td><td>1.4</td><td>1.3</td><td>1.6</td></tr><tr><td>Capitalization:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Total Equity</td><td>53 %</td><td>53 %</td><td>53 %</td><td>53 %</td><td>44 %</td></tr><tr><td>Preferred Stock Not Subject to Mandatory Redemption</td><td>1</td><td>1</td><td>1</td><td>1</td><td>1</td></tr><tr><td>Long-Term Debt (b) (c) (d)</td><td>46</td><td>46</td><td>46</td><td>46</td><td>55</td></tr><tr><td></td><td>100 %</td><td>100 %</td><td>100 %</td><td>100 %</td><td>100 %</td></tr></table>

(a) The 2012 results include the operations of NSTAR beginning April 10, 2012.

(b) The 2011 through 2014 amounts reflect reclassifications due to the adoption of new accounting guidance that changed the balance sheet presentation of debt issuance costs. Unamortized debt issuance costs are now presented as a direct reduction from the carrying amount of the debt liability rather than as a deferred cost. Prior year amounts were retrospectively adjusted to conform to the current year presentation. See Note 1C, “Summary of Significant Accounting Policies – Accounting Standards,” for further information.

(c) Includes portions due within one year.

(d) Excludes RRBs.

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

(f) Common Shareholders’ Equity adjusted for goodwill and intangibles divided by total common shares outstanding.

(g) Net Income Attributable to Common Shareholders divided by average Common Shareholders’ Equity.

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

See the Combined Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for a description of any accounting changes materially affecting the comparability of the information reflected in the tables above.



<table><tr><td></td><td>2015</td><td>2014</td><td>2013</td><td>2012 (a)</td><td>2011</td></tr><tr><td>Revenues: (Thousands)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>$ 3,608,155</td><td>$ 3,288,313</td><td>$ 3,073,181</td><td>$ 2,731,951</td><td>$ 2,091,270</td></tr><tr><td>Commercial</td><td>2,476,686</td><td>2,471,440</td><td>2,387,535</td><td>1,604,661</td><td>1,236,374</td></tr><tr><td>Industrial</td><td>326,564</td><td>348,698</td><td>339,917</td><td>753,974</td><td>252,878</td></tr><tr><td>Wholesale</td><td>411,749</td><td>447,899</td><td>486,515</td><td>357,223</td><td>350,413</td></tr><tr><td>Other and Eliminations</td><td>110,013</td><td>97,090</td><td>56,547</td><td>130,137</td><td>47,485</td></tr><tr><td>Total Electric</td><td>6,933,167</td><td>6,653,440</td><td>6,343,695</td><td>5,577,946</td><td>3,978,420</td></tr><tr><td>Natural Gas</td><td>993,662</td><td>1,002,880</td><td>855,601</td><td>572,857</td><td>430,799</td></tr><tr><td>Total - Regulated Companies</td><td>7,926,829</td><td>7,656,320</td><td>7,199,296</td><td>6,150,803</td><td>4,409,219</td></tr><tr><td>Other and Eliminations</td><td>27,998</td><td>85,536</td><td>101,908</td><td>122,984</td><td>56,438</td></tr><tr><td>Total</td><td>$ 7,954,827</td><td>$ 7,741,856</td><td>$ 7,301,204</td><td>$ 6,273,787</td><td>$ 4,465,657</td></tr><tr><td>Regulated Companies - Sales Volumes:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Electric (GWh)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>21,441</td><td>21,317</td><td>21,896</td><td>19,719</td><td>14,766</td></tr><tr><td>Commercial</td><td>27,598</td><td>27,449</td><td>27,787</td><td>24,537</td><td>14,628</td></tr><tr><td>Industrial</td><td>5,577</td><td>5,676</td><td>5,648</td><td>5,462</td><td>4,418</td></tr><tr><td>Wholesale</td><td>3,215</td><td>3,018</td><td>855</td><td>2,154</td><td>1,020</td></tr><tr><td>Total Electric</td><td>57,831</td><td>57,460</td><td>56,186</td><td>51,872</td><td>34,832</td></tr><tr><td>Natural Gas (million cubic feet)</td><td>102,999</td><td>104,191</td><td>98,258</td><td>69,894</td><td>46,880</td></tr><tr><td>Regulated Companies - Customers: (Average)</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>2,747,679</td><td>2,734,047</td><td>2,718,727</td><td>2,711,407</td><td>1,710,342</td></tr><tr><td>Commercial</td><td>374,552</td><td>373,511</td><td>371,897</td><td>370,389</td><td>199,240</td></tr><tr><td>Industrial</td><td>7,868</td><td>8,016</td><td>8,109</td><td>8,279</td><td>7,083</td></tr><tr><td>Total Electric</td><td>3,130,099</td><td>3,115,574</td><td>3,098,733</td><td>3,090,075</td><td>1,916,665</td></tr><tr><td>Natural Gas</td><td>506,175</td><td>499,186</td><td>493,563</td><td>483,770</td><td>207,753</td></tr><tr><td>Total - Regulated Companies</td><td>3,636,274</td><td>3,614,760</td><td>3,592,296</td><td>3,573,845</td><td>2,124,418</td></tr></table>

(a) The 2012 results include the operations of NSTAR beginning April 10, 2012.

CL&P Selected Financial Data (Unaudited) and CL&P Selected Sales Statistics have been omitted from this report but are set forth in the Annual Report on Form 10-K for 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. 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 and WMECO are herein collectively referred to as the “financial statements.”

On April 30, 2015, the Company’s legal name was changed from Northeast Utilities to Eversource Energy. CL&P, NSTAR Electric, PSNH and WMECO are each doing business as Eversource Energy.

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, 2014 and 2013 earnings and EPS excluding certain integration costs incurred by Eversource parent and our Regulated 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 2015, 2014 and 2013 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 more representative 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 above 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 – Regulated Companies” in Management’s Discussion and Analysis of Financial Condition and Results of Operations, herein.

## Financial Condition and Business Analysis

## Executive Summary

## Results:

- We earned $878.5 million, or $2.76 per share, in 2015, compared with $819.5 million, or $2.58 per share, in 2014. Excluding integration costs, we earned $894.3 million, or $2.81 per share, in 2015 and $841.6 million, or $2.65 per share, in 2014.

- Our electric distribution segment, which includes generation, earned $507.9 million, or $1.59 per share, in 2015, compared with $462.4 million, or $1.45 per share, in 2014. Our electric transmission segment earned $304.5 million, or $0.96 per share, in 2015, compared with $295.4 million, or $0.93 per share, in 2014. Our natural gas distribution segment earned $72.4 million, or $0.23 per share, in 2015, compared with $72.3 million, or $0.23 per share, in 2014. The 2015 electric and natural gas distribution results exclude $0.8 million of after-tax integration costs.

- Eversource parent and other companies earned $9.5 million, or $0.03 per share, in 2015, compared with $11.5 million, or $0.04 per share, in 2014. The 2015 and 2014 results exclude $15 million, or $0.05 per share, and $22.1 million, or $0.07 per share, respectively, of after-tax integration costs.

## Liquidity:

- Cash flows provided by operating activities totaled $1.4 billion in 2015, compared with $1.6 billion in 2014. Investments in property, plant and equipment totaled $1.7 billion in 2015 and $1.6 billion in 2014. Cash and cash equivalents totaled $23.9 million as of December 31, 2015, compared with $38.7 million as of December 31, 2014.

- In 2015, we issued approximately $1.23 billion of new long-term debt consisting of $450 million by Eversource parent, $350 million by CL&P, $250 million by NSTAR Electric, $100 million by NSTAR Gas, and $75 million by Yankee Gas. In 2015, we repaid $212 million of existing long-term debt consisting of $162 million by CL&P and $50 million by WMECO.

- In 2015, we paid cash dividends on common shares of $529.8 million, compared with $475.2 million in 2014. On February 3, 2016, our Board of Trustees approved a common share dividend payment of $0.445 per share, payable on March 31, 2016 to shareholders of record as of March 2, 2016. The 2016 dividend represented an increase of 6.6 percent over the dividend paid in December 2015, and is the equivalent to dividends on common shares of approximately $565 million on an annual basis.



- We project to make capital expenditures of approximately $9.2 billion from 2016 through 2019. Of the $9.2 billion, we expect to invest approximately $4.9 billion in our electric and natural gas distribution segments and $3.9 billion in our electric transmission segment. In addition, we project to invest approximately $0.4 billion in information technology and facilities upgrades and enhancements. These projections do not include capital investments related to Access Northeast or Clean Energy Connect.

Strategic, Legislative, Regulatory, Policy and Other Items:

- On December 18, 2015, the New Hampshire Site Evaluation Committee (NH SEC) accepted NPT’s application as complete allowing the formal siting process to move forward. The project is expected to be operational in the first half of 2019. On January 28, 2016, NPT bid into the three-state Clean Energy RFP process.

- The Clean Energy Connect Project is a planned transmission, wind and hydro generation project that we plan to co-develop with experienced renewable generation companies. On January 28, 2016, the Clean Energy Connect project was bid into the three-state Clean Energy RFP process. Our investment, should the Clean Energy Connect Project be selected in the RFP process, is currently estimated to be at least $400 million and will consist of the Massachusetts portion of a new 25-mile, 345 kV transmission line with a 600 MW capacity.

- On January 28, 2016, the DPU approved NSTAR Electric’s, WMECO’s, and NSTAR Gas’ three-year electric and natural gas energy efficiency plan, which was jointly developed with other Massachusetts electric distribution companies (EDCs) and natural gas distribution companies. On December 31, 2015, DEEP approved CL&P’s and Yankee Gas’ three-year electric and natural gas C&LM plan, which was jointly developed with other Connecticut EDCs and natural gas distribution companies. These electric and natural gas energy efficiency and C&LM plans include the ability to earn performance incentives as well as recover LBR for NSTAR Electric until it is operating under a decoupled rate structure.

- On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006. As a result of the DPU order, in the first quarter of 2015 NSTAR Electric increased its regulatory assets and reduced its operations and maintenance expense by $24.2 million for energy-related bad debt costs through 2014, resulting in after-tax earnings of $14.5 million. NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers and on November 20, 2015, the DPU approved NSTAR Electric’s proposed rate increase to recover these costs over a 12-month period, beginning January 1, 2016.

## Overview

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

<table><tr><td rowspan="3">(Millions of Dollars, Except Per Share Amounts)</td><td colspan="9">For the Years Ended December 31,</td></tr><tr><td colspan="3">2015</td><td colspan="3">2014</td><td colspan="3">2013</td></tr><tr><td>Amount</td><td>Per Share</td><td>Amount</td><td>Per Share</td><td>Amount</td><td>Per Share</td><td>Amount</td><td>Per Year</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders (GAAP)</td><td>$     878.5</td><td>$     2.76</td><td>$     819.5</td><td>$     2.58</td><td>$     786.0</td><td>$     2.49</td><td></td><td></td><td></td></tr><tr><td>Regulated Companies</td><td>$     884.8</td><td>$     2.78</td><td>$     830.1</td><td>$     2.61</td><td>$     774.9</td><td>$     2.45</td><td></td><td></td><td></td></tr><tr><td>Eversource Parent and Other Companies</td><td>9.5</td><td>0.03</td><td>11.5</td><td>0.04</td><td>24.9</td><td>0.08</td><td></td><td></td><td></td></tr><tr><td>Non-GAAP Earnings</td><td>894.3</td><td>2.81</td><td>841.6</td><td>2.65</td><td>799.8</td><td>2.53</td><td></td><td></td><td></td></tr><tr><td>Integration Costs (after-tax)</td><td>(15.8)</td><td>(0.05)</td><td>(22.1)</td><td>(0.07)</td><td>(13.8)</td><td>(0.04)</td><td></td><td></td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders (GAAP)</td><td>$     878.5</td><td>$     2.76</td><td>$     819.5</td><td>$     2.58</td><td>$     786.0</td><td>$     2.49</td><td></td><td></td><td></td></tr></table>

The 2015 and 2014 integration costs are associated with our branding efforts and severance costs.

Regulated Companies: Our Regulated companies consist of the electric distribution, electric transmission, and natural gas distribution segments. Generation activities of PSNH and WMECO are included in our electric distribution segment. A summary of our segment earnings and EPS is as follows:

<table><tr><td rowspan="3">(Millions of Dollars, Except Per Share Amounts)</td><td colspan="9">For the Years Ended December 31,</td></tr><tr><td colspan="3">2015</td><td colspan="3">2014</td><td colspan="3">2013</td></tr><tr><td>Amount</td><td>Per Share</td><td>Amount</td><td>Per Share</td><td>Amount</td><td>Per Share</td><td>Amount</td><td>Per Year</td><td></td></tr><tr><td>Electric Distribution</td><td>$     507.9</td><td>$     1.59</td><td>$     462.4</td><td>$     1.45</td><td>$     427.0</td><td>$     1.35</td><td></td><td></td><td></td></tr><tr><td>Electric Transmission</td><td>304.5</td><td>0.96</td><td>295.4</td><td>0.93</td><td>287.0</td><td>0.91</td><td></td><td></td><td></td></tr><tr><td>Natural Gas Distribution</td><td>72.4</td><td>0.23</td><td>72.3</td><td>0.23</td><td>60.9</td><td>0.19</td><td></td><td></td><td></td></tr><tr><td>Non-GAAP Earnings</td><td>884.8</td><td>2.78</td><td>830.1</td><td>2.61</td><td>774.9</td><td>2.45</td><td></td><td></td><td></td></tr><tr><td>Integration Costs (after-tax)</td><td>(0.8)</td><td>-</td><td>-</td><td>-</td><td>-</td><td>-</td><td></td><td></td><td></td></tr><tr><td>Net Income - Regulated Companies</td><td>$     884.0</td><td>$     2.78</td><td>$     830.1</td><td>$     2.61</td><td>$     774.9</td><td>$     2.45</td><td></td><td></td><td></td></tr></table>

The 2015 Regulated companies’ integration costs include severance in connection with cost saving initiatives.



Excluding integration costs, our electric distribution segment earnings increased $45.5 million in 2015, as compared to 2014, due primarily to the impact of the December 1, 2014 CL&P base distribution rate increase, the $27.5 million favorable earnings impact related to the resolution of NSTAR Electric’s basic service bad debt adder and the settlement with the Massachusetts Attorney General on eleven open dockets covering the CPSL program filings and the recovery of LBR related to 2009 through 2011 energy efficiency programs at NSTAR Electric, an increase in the recovery of LBR at NSTAR Electric related to 2015 energy efficiency programs, and higher retail sales volumes at NSTAR Electric and PSNH. Partially offsetting these favorable earnings impacts were a higher effective tax rate in 2015, higher property taxes, higher depreciation expense and a $5 million contribution in 2015 to create a clean energy fund in connection with the PSNH divestiture agreement.

Our electric transmission segment earnings increased $9.1 million in 2015, as compared to 2014, due primarily to the result of lower reserve charges associated with the FERC ROE complaint proceedings of $12.4 million recorded in 2015, as compared to $22.4 million recorded in 2014, and a higher transmission rate base as a result of an increased investment in our transmission infrastructure. These favorable earnings impacts were partially offset by a higher effective tax rate in 2015.

Our natural gas distribution segment earnings increased $0.1 million in 2015, as compared to 2014. Our natural gas distribution segment earnings were favorably impacted by a decrease in operations and maintenance costs primarily attributable to lower employee-related expenses, a lower effective tax rate in 2015, and additional natural gas heating customers. These favorable earnings impacts were offset by a decrease in firm natural gas sales volumes driven by record warm weather in the fourth quarter of 2015, as compared to 2014, higher depreciation expense and higher property taxes.

Eversource Parent and Other Companies: Excluding the impact of integration costs, Eversource parent and other companies had earnings of $9.5 million in 2015, compared with earnings of $11.5 million in 2014. The earnings decrease was due primarily to a higher effective tax rate at Eversource parent in 2015, as compared to 2014, higher interest expense at Eversource parent as a result of new debt issuances in January 2015, and reduced earnings in 2015 from Eversource’s unregulated electrical contracting business, which was sold in April 2015. These unfavorable earnings impacts were partially offset by a reduction in operations and maintenance costs.

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 NSTAR Electric and PSNH impact earnings (“Traditional” in the table below). For CL&P (effective December 1, 2014) and WMECO, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission approved 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. CL&P and WMECO reconcile their annual base distribution rate recovery amounts to their respective pre-established levels of baseline distribution delivery service revenues. Any difference between the allowed level of distribution revenue and the actual amount incurred during a 12-month period is adjusted through rates in the following period.

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

<table><tr><td rowspan="3">Electric</td><td colspan="3">For the Year Ended December 31, 2015 Compared to 2014</td></tr><tr><td colspan="2">Sales Volumes (GWh)</td><td rowspan="2">Percentage Increase/(Decrease)</td></tr><tr><td>2015</td><td>2014</td></tr><tr><td>Traditional:</td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>9,882</td><td>9,798</td><td>0.9%</td></tr><tr><td>Commercial</td><td>16,486</td><td>16,340</td><td>0.9%</td></tr><tr><td>Industrial</td><td>2,614</td><td>2,673</td><td>(2.2)%</td></tr><tr><td>Total - Traditional</td><td>28,982</td><td>28,811</td><td>0.6%</td></tr><tr><td>Decoupled:</td><td></td><td></td><td></td></tr><tr><td>Residential</td><td>11,559</td><td>11,519</td><td>0.3%</td></tr><tr><td>Commercial</td><td>11,112</td><td>11,109</td><td>- %</td></tr><tr><td>Industrial</td><td>2,963</td><td>3,003</td><td>(1.3)%</td></tr><tr><td>Total - Decoupled</td><td>25,634</td><td>25,631</td><td>- %</td></tr><tr><td>Total Sales Volumes</td><td>54,616</td><td>54,442</td><td>0.3%</td></tr></table>

<table><tr><td rowspan="3">Firm Natural Gas</td><td colspan="3">For the Year Ended December 31, 2015 Compared to 2014</td></tr><tr><td colspan="2">Sales Volumes (million cubic feet)</td><td rowspan="2">Percentage Increase/(Decrease)</td></tr><tr><td>2015</td><td>2014</td></tr><tr><td>Residential</td><td>38,455</td><td>38,969</td><td>(1.3)%</td></tr><tr><td>Commercial</td><td>43,006</td><td>42,977</td><td>0.1 %</td></tr><tr><td>Industrial</td><td>21,538</td><td>22,245</td><td>(3.2)%</td></tr><tr><td>Total Sales Volumes</td><td>102,999</td><td>104,191</td><td>(1.1)%</td></tr><tr><td>Total, Net of Special Contracts (1)</td><td>98,458</td><td>99,500</td><td>(1.0)%</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.



Our 2015 retail electric sales volumes at our electric utilities with a traditional rate structure (NSTAR Electric and PSNH) were slightly higher, as compared to 2014, due primarily to the impact of colder winter weather experienced in the first quarter of 2015 and warmer weather in the third quarter of 2015, partially offset by milder winter weather in the fourth quarter of 2015 throughout those service territories. In 2015, heating degree days were 1 percent lower in the Boston metropolitan area, and 5 percent lower in New Hampshire, as compared to 2014. Cooling degree days in 2015 were 19 percent higher in the Boston metropolitan area and 57 percent higher in New Hampshire, as compared to 2014. Weather-normalized retail electric sales volumes were relatively unchanged in 2015, as compared to 2014. Improved economic conditions were offset by an increase in customer conservation efforts resulting from company-sponsored energy efficiency programs.

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. In 2015, consolidated firm natural gas sales volumes were lower, as compared to 2014. The 2015 firm natural gas sales volumes were negatively impacted by record warm weather in the fourth quarter of 2015, when compared to 2014, partially offset by colder winter weather in the first quarter of 2015, as compared to 2014, throughout our natural gas service territories. Weather-normalized Eversource consolidated firm natural gas sales volumes increased 2.5 percent in 2015, as compared to 2014, due primarily to improved economic conditions as well as residential and commercial customer growth, partially offset by customer conservation efforts resulting from company-sponsored energy efficiency programs. On October 30, 2015, the DPU issued its order in the NSTAR Gas distribution rate case, which included the establishment of a revenue decoupling mechanism beginning January 1, 2016.

Prior to December 1, 2014, CL&P earned LBR related to reductions in sales volume as a result of successful energy efficiency programs. LBR was recovered from retail customers through the FMCC. Effective December 1, 2014, CL&P no longer earns LBR due to its revenue decoupling mechanism. NSTAR Electric recognized LBR of $60.6 million in 2015 and $39.9 million in 2014. On January 28, 2016, NSTAR Electric received approval of a three-year energy efficiency plan, which includes recovery of LBR until it is operating under a decoupled rate structure.

For further information, see “Regulatory Developments and Rate Matters - Massachusetts - NSTAR Electric, WMECO and NSTAR Gas Energy Efficiency Plan” and “Regulatory Developments and Rate Matters - Massachusetts - NSTAR Gas Distribution Rates” in this Management’s Discussion and Analysis of Financial Conditions and Results of Operations.

## Future Outlook

2016 EPS Guidance: We currently project 2016 earnings of between $2.90 per diluted share and $3.05 per diluted share.

## Liquidity

Consolidated: Cash and cash equivalents totaled $23.9 million as of December 31, 2015, compared with $38.7 million as of December 31, 2014.

Long-Term Debt Issuances and Repayments: On January 15, 2015, Eversource parent issued $150 million of 1.60 percent Series G Senior Notes, due to mature in 2018, and $300 million of 3.15 percent Series H Senior Notes, due to mature in 2025.

On May 20, 2015 and December 1, 2015, CL&P issued $300 million and $50 million, respectively, of 4.15 percent 2015 Series A First and Refunding Mortgage Bonds due to mature in 2045.

On September 10, 2015, Yankee Gas issued $75 million of 3.35 percent 2015 Series M First Mortgage Bonds due to mature in 2025.

On November 18, 2015, NSTAR Electric issued $250 million of 3.25 percent debentures, due to mature in 2025.

On December 8, 2015, NSTAR Gas issued $100 million of 4.35 percent Series O First Mortgage Bonds due to mature in 2045.

The proceeds of all debt issuances, net of issuance costs, were used to repay short-term borrowings and fund capital expenditures and working capital.

On April 1, 2015, CL&P repaid at maturity the $100 million 5.00 percent 2005 Series A First and Refunding Mortgage Bonds and also redeemed the $62 million 1996A Series 1.55 percent PCRBs that were subject to mandatory tender, using short term borrowings.

On August 3, 2015, WMECO repaid at maturity the $50 million 5.24 percent Series C Senior Notes, using short-term borrowings.

Long-Term Debt Issuance Authorizations: On November 25, 2015, PURA approved Yankee Gas' request to extend the authorization period for issuance of up to $125 million in long-term debt from December 31, 2015 to December 31, 2016. On December 4, 2015, the DPU authorized WMECO to issue up to $100 million in long-term debt for the period through December 31, 2016. On December 4, 2015, the DPU approved NSTAR Electric's request to extend the authorization period for issuance of up to $250 million in long-term debt from December 31, 2015 to December 31, 2016.

Credit Agreements and Commercial Paper Programs: Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas are parties to a five-year $1.45 billion revolving credit facility. On October 26, 2015, this revolving credit facility was amended and restated and the termination date was extended to September 4, 2020. Under the revolving credit facility, CL&P has a borrowing sublimit of $600 million, and PSNH and WMECO each have borrowing sublimits of $300 million. The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program. The commercial paper program allows Eversource parent to issue commercial paper as a form of short-term debt. As of December 31, 2015 and 2014, Eversource parent had approximately $1.1 billion in short-term borrowings outstanding on each date under the



Eversource parent commercial paper program, leaving $351.5 million and $348.9 million of available borrowing capacity as of December 31, 2015 and 2014, respectively. The weighted-average interest rate on these borrowings as of December 31, 2015 and 2014 was 0.72 percent and 0.43 percent, respectively. As of December 31, 2015, there were intercompany loans from Eversource parent of $277.4 million to CL&P, $231.3 million to PSNH and $143.4 million to WMECO. As of December 31, 2014, there were intercompany loans from Eversource parent of $133.4 million to CL&P, $90.5 million to PSNH and $21.4 million to WMECO.

NSTAR Electric has a five-year $450 million revolving credit facility. On October 26, 2015, this revolving credit facility was amended and restated and the termination date was extended to September 4, 2020. The facility serves to backstop NSTAR Electric's $450 million commercial paper program. As of December 31, 2015 and 2014, NSTAR Electric had $62.5 million and $302 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $387.5 million and $148 million of available borrowing capacity as of December 31, 2015 and 2014, respectively. The weighted-average interest rate on these borrowings as of December 31, 2015 and 2014 was 0.40 percent and 0.27 percent, respectively.

Cash Flows: Cash flows provided by operating activities totaled $1.4 billion in 2015, compared with $1.6 billion in 2014. The decrease in operating cash flows in 2015 compared to 2014 was due primarily to the $302 million payment made to fully satisfy the obligation with the DOE, as discussed below, and an increase in purchased power and congestion costs at NSTAR Electric, WMECO and CL&P that will be recovered in future periods. Also contributing to the decrease in operating cash flows were DOE Damages proceeds received from the Yankee Companies of $4.7 million in 2015, compared to $132 million in 2014. Partially offsetting these unfavorable cash flow impacts were a decrease of $49.2 million in Pension and PBOP Plan cash contributions in 2015, as compared to 2014, and lower federal income tax payments of approximately $324 million in 2015, as compared to 2014, primarily due to the extension of the accelerated depreciation deduction.

In late 2015, CL&P and WMECO made payments of $244.6 million and $57.4 million, respectively, to fully satisfy their obligations with the DOE, which were classified as long-term debt on the balance sheets as of December 31, 2014, for costs associated with 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 station. CL&P and WMECO divested their ownership interest in Millstone in 2001. These payments included accumulated interest of $178 million and $41.8 million for CL&P and WMECO, respectively. CL&P funded its payment with the issuance of debt, and WMECO liquidated its spent nuclear fuel trust to satisfy its obligation with the DOE.

On December 18, 2015, the “Protecting Americans from Tax Hikes” Act became law, which extended the accelerated deduction of depreciation to businesses from 2015 through 2019. This extended stimulus provides us with cash flow benefits in 2016 of approximately $275 million (including approximately $105 million for CL&P) due to a refund of taxes paid in 2015 and lower expected tax payments in 2016 of approximately $300 million.

In 2015, we paid cash dividends of $529.8 million, or $1.67 per common share, compared with $475.2 million, or $1.57 per share in 2014. Our quarterly common share dividend payment was $0.4175 per share, in 2015, as compared to $0.3925 per share, in 2014. On February 3, 2016, our Board of Trustees approved a common share dividend payment of $0.445 per share, payable on March 31, 2016 to shareholders of record as of March 2, 2016. The 2016 dividend represented an increase of 6.6 percent over the dividend paid in December 2015, and is equivalent to dividends on common shares of approximately $565 million on an annual basis.

In 2015, CL&P, NSTAR Electric, PSNH, and WMECO paid $196 million, $198 million, $106 million, and $37.2 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 2015, investments for Eversource, CL&P, NSTAR Electric, PSNH, and WMECO were $1.7 billion, $523.8 million, $469.5 million, $308 million, and $134.6 million, respectively.

Each of Eversource, CL&P, NSTAR Electric, PSNH and WMECO 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. 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. In addition, 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. These factors have resulted in current liabilities exceeding current assets by approximately $371 million and $82 million at Eversource and WMECO, respectively, as of December 31, 2015.

As of December 31, 2015, a total of $200 million of Eversource's long-term debt classified as current liabilities, all at NSTAR Electric, will be paid in the next 12 months. The remaining $28.9 million of Eversource's long-term debt classified as current liabilities relates to fair value adjustments from the merger that will be amortized in 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, PSNH and WMECO 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, PSNH and WMECO, along with the access to financial markets, will be sufficient to meet any future operating requirements and capital investment forecasted opportunities.



Credit Ratings: On April 23, 2015, S&P upgraded the corporate credit ratings by one level and changed the outlooks to stable from positive of Eversource parent, CL&P, NSTAR Electric, PSNH, WMECO, Yankee Gas and NSTAR Gas. On May 19, 2015, Moody's changed the outlooks of PSNH and WMECO to positive from stable and affirmed their corporate credit ratings. On June 2, 2015, Fitch changed the outlooks to positive from stable of CL&P, PSNH and WMECO and affirmed its corporate credit ratings of Eversource parent, CL&P, NSTAR Electric, PSNH, WMECO and NSTAR Gas.

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

<table><tr><td rowspan="2"></td><td colspan="2">Moody&#x27;s</td><td colspan="2">S&amp;P</td><td colspan="2">Fitch</td></tr><tr><td>Current</td><td>Outlook</td><td>Current</td><td>Outlook</td><td>Current</td><td>Outlook</td></tr><tr><td>Eversource Parent</td><td>Baa1</td><td>Stable</td><td>A</td><td>Stable</td><td>BBB+</td><td>Stable</td></tr><tr><td>CL&amp;P</td><td>Baa1</td><td>Stable</td><td>A</td><td>Stable</td><td>BBB+</td><td>Positive</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>Baa1</td><td>Positive</td><td>A</td><td>Stable</td><td>BBB+</td><td>Positive</td></tr><tr><td>WMECO</td><td>A3</td><td>Positive</td><td>A</td><td>Stable</td><td>BBB+</td><td>Positive</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, NSTAR Electric, and WMECO 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>Stable</td></tr><tr><td>CL&amp;P</td><td>A2</td><td>Stable</td><td>A+</td><td>Stable</td><td>A</td><td>Positive</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>A2</td><td>Positive</td><td>A+</td><td>Stable</td><td>A</td><td>Positive</td></tr><tr><td>WMECO</td><td>A3</td><td>Positive</td><td>A</td><td>Stable</td><td>A-</td><td>Positive</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 $1.9 billion in 2015, $1.7 billion in 2014, and $1.6 billion in 2013. These amounts included $102 million in 2015, $58.3 million in 2014, and $44.7 million in 2013 related to information technology and facilities upgrades and enhancements, primarily at Eversource Service and The Rocky River Realty Company.

## Natural Gas Transmission Business:

Access Northeast: Access Northeast is a natural gas pipeline and storage project (the “Project”) being developed jointly by Eversource, Spectra Energy Corp and National Grid. Access Northeast will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes and will include two new LNG storage tanks and liquefaction and vaporization facilities in Acushnet, Massachusetts that will be connected to the Algonquin gas pipeline. The Project is expected to be capable of delivering approximately 900 million cubic feet of additional natural gas per day to New England on peak demand days. Eversource and Spectra Energy Corp each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid. The total projected cost for both the pipeline and the LNG storage is expected to be approximately $3 billion with anticipated in-service dates commencing in November 2018. The Project is subject to FERC and other federal and state regulatory approvals. On November 17, 2015, the FERC accepted the Project’s request to initiate the pre-filing review process. Upon completion of the pre-filing review, a certificate application will be filed with the FERC. In late 2015, the Project bid into the New England Natural Gas Pipeline Capacity RFP conducted by certain EDCs in Massachusetts and Rhode Island, including NSTAR Electric and WMECO in Massachusetts, and in December 2015 and January 2016, those Massachusetts EDCs filed with the DPU seeking approval of the contracts for pipeline and storage capacity with the Project. We expect the Rhode Island EDC to file its selected contracts with the Rhode Island regulatory agencies in the first half of 2016. In February 2016, PSNH filed for approval with the NHPUC, its proposed contract for natural gas pipeline capacity and storage with the Project. For further information on the RFP process, see “Regulatory Developments and Rate Matters – General – New England Natural Gas Pipeline Capacity” in this Management’s Discussion and Analysis of Financial Conditions and Results of Operations.

Electric Transmission Business: Our consolidated electric transmission business capital expenditures increased by $106 million in 2015, as compared to 2014. A summary of electric transmission capital expenditures by company is as follows:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>CL&amp;P</td><td>$ 252.9</td><td>$ 259.2</td><td>$ 211.9</td><td></td></tr><tr><td>NSTAR Electric</td><td>238.2</td><td>223.8</td><td>220.8</td><td></td></tr><tr><td>PSNH</td><td>161.2</td><td>120.8</td><td>99.7</td><td></td></tr><tr><td>WMECO</td><td>116.0</td><td>68.5</td><td>87.2</td><td></td></tr><tr><td>NPT</td><td>38.3</td><td>28.3</td><td>39.9</td><td></td></tr><tr><td>Total Electric Transmission Segment</td><td>$ 806.6</td><td>$ 700.6</td><td>$ 659.5</td><td></td></tr></table>



NEEWS: The Interstate Reliability Project (IRP), the second project within the NEEWS family of projects, was fully energized on December 18, 2015. The project involved CL&P's construction of an approximately 40-mile, 345-kV overhead line from Lebanon, Connecticut to the Connecticut-Rhode Island border where it connects to transmission enhancements constructed by National Grid in Rhode Island. IRP was placed in service in December 2015 at a final cost to CL&P of $192.6 million. Through December 31, 2015, CL&P and WMECO capitalized $377.9 million and $570.6 million, respectively, in costs associated with NEEWS.

GHCC: The Greater Hartford Central Connecticut (GHCC) solutions are comprised of 27 projects and are expected to cost approximately $350 million and be placed in service from 2016 through 2018. ISO-NE posted the final Solutions Study for GHCC in late February 2015 and approved our Proposed Plan Applications on April 16, 2015. Through December 31, 2015, we have filed siting applications for five projects all of which have been approved by the Connecticut Siting Council. During 2016, fifteen projects are expected to be in active construction, and three additional siting applications are expected to be filed. All GHCC projects are expected to be completed by late 2018. As of December 31, 2015, CL&P had capitalized $50.6 million in costs associated with GHCC.

Northern Pass: Northern Pass is Eversource’s planned 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. Northern Pass will interconnect at the Québec-New Hampshire border with a planned HQ HVDC transmission line. On July 21, 2015, the DOE issued the draft Environmental Impact Statement (EIS) for Northern Pass representing a key milestone in the permitting process. On August 18, 2015, a revised route was announced with an additional 52 miles of the route underground in and around the White Mountain National Forest region. As a result, the NPT project cost estimate increased from $1.4 billion to $1.6 billion. Concurrently, NPT announced the Forward NH Plan, which is a commitment to allocate $200 million to projects associated with economic development, community betterment, and clean energy innovations to benefit the state of New Hampshire. This commitment is contingent upon the Northern Pass transmission line going into commercial operation.

On October 19, 2015, NPT filed its NH SEC application, which was accepted as complete by the NH SEC on December 18, 2015, allowing the formal siting process to move forward. In response to requests by the New Hampshire congressional delegation, the DOE announced that it would issue a supplement to the draft EIS. Public hearings on the draft EIS will be held in March 2016. The DOE has asked for comments by April 4, 2016. The project is expected to be operational in the first half of 2019. On January 28, 2016, NPT bid into the three-state Clean Energy RFP process. For further information on the RFP process, see “Regulatory Developments and Rate Matters – General – Clean Energy RFP” in this Management’s Discussion and Analysis of Financial Conditions and Results of Operations.

Clean Energy Connect: The Clean Energy Connect project is a planned transmission, wind and hydro generation project that we plan to co-develop with experienced renewable generation companies. On January 28, 2016, the Clean Energy Connect project was bid into the three-state Clean Energy RFP process. Our investment, should the Clean Energy Connect Project be selected in the RFP process, is currently estimated to be at least $400 million, and would involve the construction of a new 25-mile, 345kV transmission line with a 600 MW capacity from western Massachusetts to eastern New York.

Greater Boston Reliability Solutions: In February 2015, ISO-NE selected Eversource’s and National Grid’s proposed Greater Boston and New Hampshire Solution (Solution) to satisfy the requirements identified in the Greater Boston study. The Solution consists of a portfolio of electric transmission upgrades straddling southern New Hampshire and northern Massachusetts in the Merrimack Valley and continuing into the greater Boston metropolitan area. We are pursuing the necessary regulatory approvals and have filed several siting applications in Massachusetts and New Hampshire. We estimate our portion of the investment in the Solution will be $544 million.



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

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2015</td><td colspan="2">2014</td><td>2013</td></tr><tr><td>CL&amp;P:</td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Business</td><td>$     141.1</td><td>$     120.2</td><td>$     60.9</td><td></td></tr><tr><td>Aging Infrastructure</td><td>151.0</td><td>118.0</td><td>160.7</td><td></td></tr><tr><td>Load Growth</td><td>42.2</td><td>66.3</td><td>76.9</td><td></td></tr><tr><td>Total CL&amp;P</td><td>334.3</td><td>304.5</td><td>298.5</td><td></td></tr><tr><td>NSTAR Electric:</td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Business</td><td>108.7</td><td>99.0</td><td>98.5</td><td></td></tr><tr><td>Aging Infrastructure</td><td>103.1</td><td>104.2</td><td>110.6</td><td></td></tr><tr><td>Load Growth</td><td>51.9</td><td>43.1</td><td>53.6</td><td></td></tr><tr><td>Total NSTAR Electric</td><td>263.7</td><td>246.3</td><td>262.7</td><td></td></tr><tr><td>PSNH:</td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Business</td><td>59.2</td><td>62.1</td><td>22.7</td><td></td></tr><tr><td>Aging Infrastructure</td><td>57.3</td><td>45.3</td><td>50.5</td><td></td></tr><tr><td>Load Growth</td><td>25.5</td><td>27.1</td><td>29.3</td><td></td></tr><tr><td>Total PSNH</td><td>142.0</td><td>134.5</td><td>102.5</td><td></td></tr><tr><td>WMECO:</td><td></td><td></td><td></td><td></td></tr><tr><td>Basic Business</td><td>18.2</td><td>19.0</td><td>7.9</td><td></td></tr><tr><td>Aging Infrastructure</td><td>18.5</td><td>16.1</td><td>24.6</td><td></td></tr><tr><td>Load Growth</td><td>6.6</td><td>6.1</td><td>9.2</td><td></td></tr><tr><td>Total WMECO</td><td>43.3</td><td>41.2</td><td>41.7</td><td></td></tr><tr><td>Total - Electric Distribution (excluding Generation)</td><td>783.3</td><td>726.5</td><td>705.4</td><td></td></tr><tr><td>Other Distribution</td><td>-</td><td>-</td><td>0.7</td><td></td></tr><tr><td>PSNH Generation</td><td>33.3</td><td>13.1</td><td>9.7</td><td></td></tr><tr><td>WMECO Generation</td><td>-</td><td>7.6</td><td>4.5</td><td></td></tr><tr><td>Natural Gas</td><td>212.6</td><td>193.7</td><td>175.2</td><td></td></tr><tr><td>Total Electric and Natural Gas Distribution Segment</td><td>$     1,029.2</td><td>$     940.9</td><td>$     895.5</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 includes requests for new business and capacity additions on distribution lines and substation additions and expansions.

Natural Gas Distribution Business Expansion and Enhancement: In 2013, in accordance with Connecticut law and regulations, PURA approved a comprehensive joint natural gas infrastructure expansion plan (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 estimated that its portion of the plan would 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 March 20, 2015, Yankee Gas filed its initial System Expansion (SE) Rate reconciliation for 2014. The proposed SE rate was approved by the PURA for implementation as of April 1, 2015, pending final PURA approval following a contested hearing.

In October 2014, pursuant to new legislation, 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 $255 million for the period 2016 through 2019 for the GSEP.



Projected Capital Expenditures: A summary of the projected capital expenditures for the Regulated companies' electric transmission and for the total electric distribution, generation, and natural gas distribution businesses for 2016 through 2019, 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>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2016-2019 Total</td><td></td><td></td></tr><tr><td>CL&amp;P Transmission</td><td>$ 351</td><td>$ 250</td><td>$ 215</td><td>$ 157</td><td>$ 973</td><td></td><td></td></tr><tr><td>NSTAR Electric Transmission</td><td>302</td><td>216</td><td>238</td><td>149</td><td>905</td><td></td><td></td></tr><tr><td>PSNH Transmission</td><td>112</td><td>65</td><td>38</td><td>56</td><td>271</td><td></td><td></td></tr><tr><td>WMECO Transmission</td><td>115</td><td>78</td><td>22</td><td>40</td><td>255</td><td></td><td></td></tr><tr><td>NPT</td><td>31</td><td>684</td><td>636</td><td>149</td><td>1,500</td><td></td><td></td></tr><tr><td>Total Electric Transmission</td><td>$ 911</td><td>$ 1,293</td><td>$ 1,149</td><td>$ 551</td><td>$ 3,904</td><td></td><td></td></tr><tr><td>Electric Distribution</td><td>$ 892</td><td>$ 963</td><td>$ 888</td><td>$ 840</td><td>$ 3,583</td><td></td><td></td></tr><tr><td>Generation</td><td>20</td><td>-</td><td>-</td><td>-</td><td>20</td><td></td><td></td></tr><tr><td>Natural Gas</td><td>284</td><td>318</td><td>339</td><td>357</td><td>1,298</td><td></td><td></td></tr><tr><td>Total Distribution</td><td>$ 1,196</td><td>$ 1,281</td><td>$ 1,227</td><td>$ 1,197</td><td>$ 4,901</td><td></td><td></td></tr><tr><td>Information Technology and All Other</td><td>$ 105</td><td>$ 88</td><td>$ 82</td><td>$ 87</td><td>$ 362</td><td></td><td></td></tr><tr><td>Total</td><td>$ 2,212</td><td>$ 2,662</td><td>$ 2,458</td><td>$ 1,835</td><td>$ 9,167</td><td></td><td></td></tr></table>

The projections do not include capital investments related to Access Northeast or Clean Energy Connect. Actual capital expenditures could vary from the projected amounts for the companies and years above.

## FERC Regulatory Issues

FERC ROE Complaints: Three separate complaints have been filed at FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (the “Complainants”). In these three separate complaints, the Complainants challenged the NETOs’ base ROE of 11.14 percent that had been utilized since 2006 and sought an order to reduce it prospectively from the date of the final FERC order and for the 15-month complaint refund periods stipulated in the separate complaints. In 2014, the FERC ordered a 10.57 percent base ROE for the first complaint refund period and prospectively from October 16, 2014, and that a utility’s total or maximum ROE shall not exceed the top of the new zone of reasonableness, which was set at 11.74 percent. The NETOs and the Complainants sought rehearing from FERC. In late 2014, the NETOs made a compliance filing and the Company began issuing refunds to customers from the first complaint period.

As a result of the actions taken by the FERC and other developments in the first complaint matter, the Company recorded reserves at its electric subsidiaries in 2015, 2014 and 2013. In 2015, Eversource recognized an after-tax charge to earnings (excluding interest) of $12.4 million, of which $7.9 million was recorded at CL&P, $1.4 million at NSTAR Electric, $0.6 million at PSNH, and $2.5 million at WMECO. The net aggregate after-tax charge to earnings (excluding interest) in 2014 totaled $22.4 million, of which $12.4 million was recorded at CL&P, $4.9 million at NSTAR Electric, $1.7 million at PSNH and $3.4 million at WMECO. The aggregate after-tax charge to earnings (excluding interest) in 2013 totaled $14.3 million, of which $7.7 million was recorded at CL&P, $3.4 million at NSTAR Electric, $1.4 million at PSNH and $1.8 million at WMECO. The NETOs and Complainants have filed appeals to the D.C. Circuit Court of Appeals. A court decision is expected in late 2016.

For the second and third complaints, the state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced to an amount lower than 10.57 percent. The NETOs believe that the Complainants’ positions are without merit, and the existing base ROE of 10.57 percent is just and reasonable and should be maintained. The FERC ALJ’s initial recommendation is expected by March 31, 2016. A final FERC order is expected in late 2016 or early 2017.

As of December 31, 2015, CL&P, NSTAR Electric, PSNH, and WMECO had approximately $2.7 billion of aggregate shareholder equity invested in their transmission facilities. As a result, each 10 basis point change in the authorized base ROE would change annual consolidated earnings by an approximate $2.7 million. Although we are uncertain on the final outcome of the second and third complaints regarding the ROE, we believe the current reserves established are appropriate to reflect probable and reasonably estimable refunds.

FERC Order No. 1000: On August 15, 2014, the D.C. Circuit Court of Appeals upheld the FERC’s authority to order major changes to transmission planning and cost allocation in FERC Order No. 1000 and Order No. 1000-A, including transmission planning for public policy needs, and the requirement that utilities remove from their transmission tariffs their rights of first refusal to build transmission. On March 19, 2015, the FERC acted on all rehearing requests filed by the NETOs, including CL&P, NSTAR Electric, PSNH and WMECO, and other parties and accepted the November 2013 compliance filing made by ISO-NE and the NETOs, subject to further compliance. The FERC accepted our proposal that the new competitive transmission planning process will not apply to certain projects, which have been declared as the preferred solution by ISO-NE, unless ISO-NE later decides a solution must be re-evaluated. The FERC determined on rehearing that we can restore provisions that recognize the NETOs’ rights to retain use and control of their existing rights of ways. Final compliance was filed by the NETOs in November 2015 and was accepted by the FERC on December 14, 2015.

Additionally, the FERC affirmed that it can eliminate our right of first refusal to build transmission in New England even though the FERC previously approved and granted special protections to these rights. The NETOs filed an appeal to the D.C. Circuit Court of Appeals, challenging this FERC ruling. State regulators also filed an appeal, challenging FERC’s determination that ISO-NE should select public policy transmission projects after a competitive process. The Court is expected to resolve the appeals in 2016.



## General:

Clean Energy RFP: In February 2015, pursuant to clean energy goals established in three New England states (Connecticut, Massachusetts and Rhode Island), CL&P, NSTAR Electric, WMECO, other EDCs, and state agencies in the three states jointly developed and issued a draft request for proposal (RFP) for clean energy resources (including Class I renewable generation and large hydroelectric generation). The draft RFP solicits offers for clean energy and the transmission to deliver that energy to the three states. The procurement will allow the states to identify large-scale projects that may offer the potential to meet their clean energy goals in a cost-effective manner when entered into jointly, while complying with the clean energy statutes within the three states.

The DPU and the Rhode Island Public Utilities Commission (PUC) approved the draft RFP that was jointly submitted by certain EDCs. The draft RFP encompassed the timetable and method for the solicitation and execution of any associated long-term contracts. On August 31, 2015, the DEEP issued a notice of proceeding on the Connecticut portion of the draft RFP and accepted public comment through September 30, 2015. On November 12, 2015, the DEEP and the Massachusetts and Rhode Island EDCs issued the RFP to a wide range of potentially interested bidders. In late January 2016, bidders submitted project proposals, among which were the Northern Pass and Clean Energy Connect projects, selection of which will take place between April and July 2016. The expected timeframe within which EDCs will execute contracts and submit them for regulatory commission approval from the respective state regulators is from June through October 2016 with approval expected in late 2016.

New England Natural Gas Pipeline Capacity: In 2014, the six New England states began to explore ways to address and mitigate winter natural gas price volatility and the associated impact on electric power supply costs attributable to winter pipeline capacity constraints. Five states are currently pursuing natural gas capacity expansion efforts. In 2014, Rhode Island approved legislation authorizing the Rhode Island Division of Public Utilities and Carriers and the Office of Energy Resources to participate in the RFP process and file proposals with the PUC. In late 2015, Access Northeast bid on the natural gas pipeline and storage RFP issued by the Rhode Island EDC. We expect the EDC will file their selected contracts with the PUC in the first half of 2016. The Massachusetts DPU determined that it has the authority to allow EDCs to contract for natural gas pipeline capacity and in late 2015, certain Massachusetts EDCs, including NSTAR Electric and WMECO, issued a natural gas pipeline capacity RFP. In December 2015 and January 2016, those Massachusetts EDCs filed with the DPU seeking approval of the contracts for pipeline and storage capacity, including Access Northeast. On January 19, 2016, the NHPUC issued an order accepting a staff report that concluded that the NHPUC could approve contracts between pipelines and EDCs if they were shown to reduce electricity costs and be in the public interest. In February 2016, PSNH filed for approval with the NHPUC, its proposed contract for natural gas pipeline capacity and storage with Access Northeast. The Connecticut DEEP expects to provide an opportunity for public comment on a natural gas pipeline capacity RFP in the first quarter of 2016.

## Electric and Natural Gas Base Distribution Rates:

Each Eversource utility subsidiary is subject to the regulatory jurisdiction of the state in which it operates: CL&P and Yankee Gas operate in Connecticut and are subject to PURA regulation; NSTAR Electric, WMECO and NSTAR Gas operate in Massachusetts and are subject to DPU regulation; and PSNH operates in New Hampshire and is 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, CL&P distribution rates were established in a 2014 PURA approved rate case. Yankee Gas distribution rates were established in a 2011 PURA approved rate case. In Massachusetts, electric utility companies are required to file at least one distribution rate case every five years, and natural gas companies to file at least one distribution rate case every 10 years, and those companies are limited to one settlement agreement in any 10-year period. NSTAR Electric and WMECO were subject to a base distribution rate freeze through December 31, 2015. NSTAR Gas distribution rates effective January 1, 2016 were established in an October 30, 2015 DPU distribution rate order. See Massachusetts – NSTAR Gas Distribution Rates in this Regulatory Developments and Rate Matters section for further information. 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, and increased funding via rates, of PSNH's reliability enhancement program. See New Hampshire - Distribution Rates in this Regulatory Developments and Rate Matters section for further information.

## 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 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 costs 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.



## Connecticut:

CL&P Distribution Rates: In December 2014, the PURA granted a re-opener request to CL&P's base distribution rate application for further review of the appropriate balance of ADIT utilized in the calculation of rate base. On July 2, 2015, the PURA issued a final order that approved a settlement agreement filed on May 19, 2015 between CL&P and the PURA Prosecutorial Staff. The order allows for an increase to rate base of approximately $163 million associated with ADIT, including a regulatory asset to recover the incremental revenue requirement for the period December 1, 2014 through November 30, 2015 over a subsequent 24-month period. The rate base increase provided an increase to total allowed annual revenue requirements of $18.4 million beginning December 1, 2014. As part of the settlement agreement, the $18.4 million for the period December 1, 2014 through November 30, 2015 was recorded as a regulatory asset with a corresponding increase in Operating Revenues, and is being collected from customers in rates over a 24-month period beginning December 1, 2015.

CL&P and Yankee Gas Conservation and Load Management Plan: On December 31, 2015, DEEP approved the three-year electric and natural gas C&LM plan filed by CL&P and Yankee Gas, which was jointly developed with the Connecticut EDCs and natural gas distribution companies. The C&LM plan, which covers the years 2016 through 2018, was built upon the continued success and momentum of the previous C&LM plans and includes performance incentives totaling $24 million over the three-year period related to proposed savings goals for CL&P and Yankee Gas.

Yankee Gas Settlement Agreement: On April 29, 2015, the PURA approved a settlement agreement entered into among Yankee Gas, the Connecticut Office of Consumer Counsel, and the PURA Staff, which eliminated the requirement to file a base distribution rate case in 2015. Under the terms of the settlement agreement, Yankee Gas provided a $1.5 million rate credit to firm customers beginning in December 2015 and continued through February 2016, 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. Additionally, Yankee Gas shall forgo its right to file a rate case for an increase in its base distribution rates prior to January 1, 2017. This does not impact the rates charged under the Connecticut comprehensive energy strategy (CES) program. The settlement agreement also resolved two pending regulatory proceedings before the PURA pertaining to a review of Yankee Gas' overearnings. In 2015, Yankee Gas recorded the $1.5 million expected refund to customers as a reduction to operating revenues.

## Massachusetts:

NSTAR Electric and NSTAR Gas Comprehensive Settlement Agreement: On March 2, 2015, the DPU approved the comprehensive settlement agreement between NSTAR Electric, NSTAR Gas and the Massachusetts Attorney General (the "Settlement") as filed with the DPU on December 31, 2014. The Settlement resolved the outstanding NSTAR Electric CPSL program filings for 2006 through 2011, the NSTAR Electric and NSTAR Gas PAM and energy efficiency-related customer billing adjustments reported in 2012, and the recovery of LBR related to NSTAR Electric's energy efficiency programs for 2009 through 2011 (11 dockets in total). In the first quarter of 2015, as a result of the DPU order, NSTAR Electric and NSTAR Gas commenced refunding a combined $44.7 million to customers, which was recorded as a regulatory liability. Refunds to customers will continue through December 2016. As a result of the Settlement, NSTAR Electric increased its operating revenues and decreased its amortization expense in 2015, resulting in the recognition of a $13 million after-tax benefit.

NSTAR Electric Basic Service Bad Debt Adder: On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006. As a result of the DPU order, in the first quarter of 2015, NSTAR Electric increased its regulatory assets and reduced its operations and maintenance expense by an under recovered amount of $24.2 million for energy-related bad debt costs through 2014, resulting in after-tax earnings of $14.5 million. NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers and on November 20, 2015, the DPU approved NSTAR Electric’s proposed rate increase to recover these costs over a 12-month period, beginning January 1, 2016.

NSTAR Electric and WMECO Grid Modernization Plan: As part of the DPU’s investigation into the modernization of the electric grid, in August 2015, NSTAR Electric and WMECO filed a comprehensive ten-year plan with the DPU. The plan focuses on technologies and investments that modernize the grid with proposed investments in equipment that reduces the frequency and duration of power outages, optimizes and manages electrical demand, integrates distributed energy resources, and improves workforce and asset management. The plan includes incremental spending of approximately $430 million over the first five years, which would be recovered from customers in rates, and is pending DPU review and approval. There is currently no timeline for the DPU to take any action on this plan.

NSTAR Electric, WMECO and NSTAR Gas Energy Efficiency Plan: The Massachusetts EDCs and natural gas distribution companies have increased their energy efficiency savings achievements significantly since the enactment of the Green Communities Act in 2008, with electric savings almost tripling between 2008 and 2014. On January 28, 2016, the DPU issued an order approving NSTAR Electric's, WMECO's, and NSTAR Gas' three-year electric and natural gas energy efficiency plan, which was jointly developed with other Massachusetts EDCs and natural gas distribution companies. As part of this plan, which covers the years 2016 through 2018, NSTAR Electric, WMECO, and NSTAR Gas will maintain aggressive savings goals. The plan includes the ability to earn performance incentives related to these aggressive savings goals totaling $58 million over the three-year period for NSTAR Electric, WMECO and NSTAR Gas, as well as recovery of LBR of approximately $50 million on an annual basis for NSTAR Electric until it is operating under a decoupled rate structure.

NSTAR Electric DPU Safety and Reliability Programs: The safety and reliability programs allowed NSTAR Electric to recover $15 million per year, through December 31, 2015, related to DPU approved safety and reliability programs, which are designed to mitigate stray voltage and repair and replace portions of the system to increase and enhance customer safety.

NSTAR Gas Distribution Rates: On October 30, 2015, the DPU issued its order in the NSTAR Gas distribution rate case, which approved 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 (GSA), 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. On November 19, 2015, NSTAR Gas filed a motion for reconsideration of the order with the DPU seeking the correction of mathematical errors and other plant and cost of service items.

As a result of this order, Eversource recorded regulatory deferrals for costs that have been approved for recovery or are expected to be approved for recovery in future rate proceedings, which resulted in the recognition of a $10.3 million after-tax benefit in 2015. Included in this amount is a $6.3 million after-tax benefit recorded at NSTAR Electric for certain uncollectible hardship accounts receivable that are expected to be recovered in future rates given the allowed recoveries of uncollectible hardship accounts receivable by WMECO and NSTAR Gas.

NSTAR Gas - Gas Service Agreement: On April 29, 2015, the DPU approved the GSA, subject to DPU modifications, between NSTAR Gas and Hopkinton LNG Corp. (HOPCO), an indirect, wholly-owned subsidiary of Eversource. On October 30, 2015, the DPU issued its order in the NSTAR Gas distribution rate case that required minor changes to the GSA. On May 22, 2015 and November 17, 2015, we filed revised GSAs with the DPU reflecting these modifications. The GSA effectively replaces the former gas services agreement in place between NSTAR Gas and HOPCO, maintains NSTAR Gas Company's entitlement to 100 percent of the current capacity of the HOPCO facilities, and provides for the recovery of costs associated with planned capital expenditures at the HOPCO facilities. We currently estimate the HOPCO facilities' capital expenditures to be approximately $200 million, most of which will be invested and placed into service in the first five years of the GSA. The GSA has a 30-year term commencing on January 1, 2016.

## New Hampshire:

Distribution Rates: PSNH distribution rates were established in a settlement approved by the NHPUC in 2010. Rates established therein will continue until changed by the NHPUC in a subsequent distribution rate proceeding. In June 2015, PSNH sought and obtained approval for a distribution rate increase to fund continuation of the reliability enhancement program beyond the end of the PSNH’s 2010 distribution rate settlement.

## Generation Divestiture:

On June 10, 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement (the Agreement) with the New Hampshire Office of Energy and Planning, certain members of the NHPUC staff, the Office of Consumer Advocate, two State Senators, and several other parties. The Agreement was filed with the NHPUC on the same day. Under the terms of the Agreement, PSNH has agreed to divest its generation assets upon NHPUC approval. The Agreement is designed to provide a resolution of issues pertaining to PSNH’s generation assets in pending regulatory proceedings before the NHPUC. The Agreement provided for the Clean Air Project prudence proceeding to be resolved and all remaining Clean Air Project costs to be included in rates effective January 1, 2016. As part of the Agreement, PSNH has agreed to forego recovery of $25 million of the deferred equity return related to the Clean Air Project. In addition, PSNH will not seek a general distribution rate increase effective before July 1, 2017 and will contribute $5 million to create a clean energy fund, which will not be recoverable from its customers. In 2015, PSNH recorded the $5 million contribution as a long-term liability and an increase to Operations and Maintenance expense on the statements of income.

Upon completion of the divestiture process, all remaining stranded costs will be recovered via bonds that will be secured by a non-bypassable charge or through other recoveries in rates billed to PSNH’s customers. For further information on the securitization legislation that was signed into law on July 9, 2015, see “Legislative and Policy Matters – New Hampshire” in this Management’s Discussion and Analysis of Financial Conditions and Results of Operations.

On January 26, 2016, Advisory Staff of the NHPUC and the parties to the Agreement filed a stipulation with the NHPUC agreeing that near-term divestiture of PSNH’s generation was in the public interest and that the Agreement should be approved. Implementation of the Agreement is subject to NHPUC approval, which is expected in early 2016.

We believe that full recovery of PSNH’s generation assets is probable through a combination of cash flows during the remaining operating period, sales proceeds upon divestiture, and recovery of stranded costs in future rates.

Clean Air Project Prudence Proceeding: The Clean Air Project, which involved the installation of wet scrubber technology at PSNH’s Merrimack coal-fired generation station in Bow, New Hampshire, pursuant to state law, was placed in service in September 2011. In April 2012, the NHPUC issued an order authorizing temporary rates to recover a significant portion of the Clean Air Project costs.

Pursuant to the Agreement, on December 22, 2015, the NHPUC approved PSNH’s request to increase its default energy service rate for full recovery of costs (including a return) related to the Clean Air Project, as well as a deferred equity return, effective January 1, 2016. The approved energy supply portion of the 2016 rate is 9.99 cents per kWh (including all Clean Energy Project-related costs), and the SCRC rate for 2016 is a credit to customers of 0.017 cents per kWh.

## Legislative and Policy Matters

Federal: On December 18, 2015, the “Protecting Americans from Tax Hikes” Act became law, which extended the accelerated deduction of depreciation to businesses from 2015 through 2019. This extended stimulus provides us with cash flow benefits of approximately $275 million (including approximately $105 million for CL&P) due to a refund of taxes paid in 2015 and lower expected tax payments in 2016 of approximately $300 million.



New Hampshire: On July 9, 2015, the Governor of New Hampshire signed “An Act Relative to Electric Rate Reduction Financing” (the Act) permitting the NHPUC to issue finance orders that authorize the issuance of rate reduction bonds in accordance with the PSNH divestiture agreement and the expected NHPUC divestiture order, regarding cost recovery of the Clean Air project and divestiture of PSNH’s remaining generation plants.

Connecticut: In 2015, the state of Connecticut enacted several changes to its corporate tax laws. Among the changes, commencing as of January 1, 2015, is the reduction in the amount of tax credits that corporations can utilize against its tax liability in a year and a continuation of the corporate income tax surcharge through 2018, which effectively increases the state corporate tax rate to 9 percent for the years 2016 and 2017 and 8.25 percent for 2018. Also, effective January 1, 2016, all Connecticut companies have a mandatory unitary tax filing requirement. We continue to review the tax law changes and their impact on the effective tax rates of Eversource and CL&P.

## 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 our best 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.

The Regulated companies estimate unbilled sales monthly using the daily load cycle method. The daily load cycle method allocates billed sales to the current calendar month based on the daily load for each billing cycle. The billed sales are subtracted from total month load, net of delivery losses, to estimate unbilled sales. Unbilled revenues are estimated by first allocating unbilled sales to the respective customer classes, then applying an estimated rate by customer class to those sales. The estimate of unbilled revenues is sensitive to factors such as energy demand, weather and changes in the composition of customer classes that can significantly impact the amount of revenues recorded at NSTAR Electric and PSNH because they do not have a revenue decoupling mechanism. CL&P and WMECO record a regulatory deferral to reflect the actual allowed amount of revenue for decoupling, and unbilled revenues estimation is not critical to CL&P and WMECO.

Pension and PBOP: We sponsor Pension and PBOP Plans to provide retirement benefits to our employees. Effective January 1, 2015, the two Pension Plans were merged into one Pension Plan, sponsored by Eversource Service, and our PBOP Plans were merged into one PBOP Plan, sponsored by Eversource Service. 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, mortality assumptions, and health care cost trend rates. 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.

Pre-tax net periodic benefit expense for the Pension Plan (excluding the SERP Plans) was $124.2 million, $118.4 million and $236.3 million for the years ended December 31, 2015, 2014 and 2013, respectively. The pre-tax net periodic benefit expense for the PBOP Plan was $2.4 million, $8.1 million and $32.6 million for the years ended December 31, 2015, 2014 and 2013, respectively.



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, 2015, 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 2016 pension and PBOP expense, our expected long-term rate of return of 8.25 percent for all plans was used reflecting our target asset allocations.

Discount Rate: Payment obligations related to the Pension 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 2015 pension 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, 2015, the discount rates used to determine the funded status were 4.6 percent for the Pension Plan and 4.62 percent for the PBOP Plan. As of December 31, 2014, the discount rates used were 4.2 percent for the Pension Plans and 4.22 percent for the PBOP Plans. The increase in the discount rate used to calculate the funded status resulted in a decrease on the Pension and PBOP Plan’s liability of approximately $267 million and $60 million, respectively, as of December 31, 2015.

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 Plan participants receive in the future. As of both December 31, 2015 and 2014, the compensation/progression rate used to determine the funded status was 3.5 percent.

Mortality Assumptions: Assumptions as to mortality of the participants in our Pension 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. During 2014, the Society of Actuaries released a series of updated mortality tables resulting from studies that measured mortality rates for various groups of individuals. The updated mortality tables released in 2014 increased the life expectancy of plan participants by three to five years and had the effect of increasing the estimated benefits to be provided to plan participants. The impact of adopting the updated mortality tables on Eversource’s liability as of December 31, 2014 was an increase of approximately $340 million and $82 million for the Pension and PBOP Plans, respectively. In 2015, 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 new mortality scale resulted in a decrease of $48 million and $23 million for the Pension and PBOP Plans’ liability, respectively, as of December 31, 2015.

Actuarial Determination of Expense: Pension 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.

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 Plan (excluding the SERP Plans) will be approximately $65 million and income for the PBOP Plan will be approximately $7.7 million, respectively, in 2016. 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 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 2016 service costs are 4.91 percent and 5.14 percent for the Pension and PBOP Plans, respectively. The discount rates used to estimate the 2016 interest costs are 3.80 percent and 3.72 percent for the Pension and PBOP Plans, respectively. Pension 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. Pension and PBOP expense charged to earnings is net of the amounts capitalized.

Our policy is to annually fund the Pension Plan in an amount at least equal to the amount that will satisfy all federal funding requirements. We contributed $154.6 million to the Pension Plan in 2015. We currently estimate approximately $146 million of contributions to the Pension Plan in 2016.

For the PBOP Plan, it is our policy to annually fund the PBOP Plan though tax deductible contributions to external trusts. We contributed $7.9 million to the PBOP Plan in 2015. We currently estimate approximately $9.5 million in contributions to the PBOP Plan in 2016.

Sensitivity Analysis: The following represents the hypothetical increase to the Pension Plan’s (excluding the SERP Plans) and PBOP Plan’s 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="3">As of December 31,</td><td colspan="3"></td></tr><tr><td>Assumption Change</td><td colspan="3">2015</td><td>2014</td><td>2015</td><td>2014</td></tr><tr><td>Eversource</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Lower expected long-term rate of return</td><td>$ 20.6</td><td>$</td><td>19.3</td><td>$ 4.2</td><td>$</td><td>4.0</td></tr><tr><td>Lower discount rate</td><td>$ 26.3</td><td>$</td><td>19.1</td><td>$ 6.2</td><td>$</td><td>2.2</td></tr><tr><td>Higher compensation rate</td><td>$ 12.4</td><td>$</td><td>10.2</td><td>N/A</td><td></td><td>N/A</td></tr></table>



Health Care Cost: As of December 31, 2015, the health care cost trend rate assumption used to determine the PBOP Plan’s year end funded status was 6.25 percent, subsequently decreasing to an ultimate rate of 4.5 percent in 2023. The effect of a hypothetical increase in the health care cost trend rate by one percentage point would be an increase to the service and interest cost components of PBOP Plan expense by $8.5 million in 2015, and a $115.3 million increase to the PBOP obligation.

Goodwill: We have recorded approximately $3.5 billion of goodwill associated with previous mergers and acquisitions. We have identified our reporting units for purposes of allocating and testing goodwill as Electric Distribution, Electric Transmission and Natural Gas Distribution. 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, PSNH and WMECO. The Natural Gas Distribution reporting unit includes the carrying values of NSTAR Gas and Yankee Gas. As of December 31, 2015, goodwill was allocated to the reporting units as follows: $2.5 billion to Electric Distribution, $0.6 billion to Electric Transmission, and $0.4 billion to Natural Gas Distribution.

We are required to test goodwill balances for impairment at least annually by considering the fair values of the reporting units, which requires us to use estimates and judgments. We have selected October 1 \( ^{st} \)  of each year as the annual goodwill impairment testing date. Goodwill impairment is deemed to exist if the carrying value 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, 2015 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 2015 goodwill impairment test resulted in a conclusion that goodwill is not impaired and no reporting unit is at risk of a goodwill impairment.

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.

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



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

## Other Matters

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

Contractual Obligations and Commercial Commitments: Information regarding our contractual obligations and commercial commitments as of December 31, 2015 is summarized annually through 2020 and thereafter as follows:

<table><tr><td>Eversource(Millions of Dollars)</td><td>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>Thereafter</td><td>Total</td></tr><tr><td>Long-term debt maturities (a)</td><td>$ 200.0</td><td>$ 745.0</td><td>$ 960.0</td><td>$ 800.0</td><td>$ 295.0</td><td>$ 5,736.6</td><td>$ 8,736.6</td></tr><tr><td>Estimated interest payments on existing debt (b)</td><td>371.2</td><td>366.6</td><td>313.1</td><td>284.2</td><td>245.8</td><td>2,849.6</td><td>4,430.5</td></tr><tr><td>Capital leases (c)</td><td>2.2</td><td>2.1</td><td>2.1</td><td>2.0</td><td>2.0</td><td>1.4</td><td>11.8</td></tr><tr><td>Operating leases (d)</td><td>16.4</td><td>13.8</td><td>10.4</td><td>8.5</td><td>6.8</td><td>15.4</td><td>71.3</td></tr><tr><td>Funding of pension obligations (d)(e)</td><td>146.0</td><td>167.5</td><td>114.5</td><td>70.6</td><td>20.2</td><td>-</td><td>518.8</td></tr><tr><td>Funding of PBOP obligations (d)</td><td>9.5</td><td>9.2</td><td>9.4</td><td>9.6</td><td>-</td><td>-</td><td>37.7</td></tr><tr><td>Estimated future annual long-term contractual costs (f)</td><td>684.5</td><td>590.6</td><td>442.3</td><td>376.2</td><td>344.9</td><td>2,371.7</td><td>4,810.2</td></tr><tr><td>Total (g)</td><td>$ 1,429.8</td><td>$ 1,894.8</td><td>$ 1,851.8</td><td>$ 1,551.1</td><td>$ 914.7</td><td>$ 10,974.7</td><td>$ 18,616.9</td></tr><tr><td>CL&amp;P(Millions of Dollars)</td><td>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>Thereafter</td><td>Total</td></tr><tr><td>Long-term debt maturities (a)</td><td>-</td><td>$ 250.0</td><td>$ 300.0</td><td>$ 250.0</td><td>-</td><td>$ 1,990.3</td><td>$ 2,790.3</td></tr><tr><td>Estimated interest payments on existing debt (b)</td><td>140.0</td><td>136.0</td><td>117.8</td><td>102.4</td><td>95.5</td><td>1,402.7</td><td>1,994.4</td></tr><tr><td>Capital leases (c)</td><td>1.9</td><td>1.9</td><td>2.0</td><td>2.0</td><td>2.0</td><td>1.4</td><td>11.2</td></tr><tr><td>Operating leases (d)</td><td>2.9</td><td>2.0</td><td>1.3</td><td>1.0</td><td>0.7</td><td>1.7</td><td>9.6</td></tr><tr><td>Funding of pension obligations (d)(e)</td><td>0.4</td><td>15.5</td><td>26.3</td><td>21.1</td><td>6.1</td><td>-</td><td>69.4</td></tr><tr><td>Estimated future annual long-term contractual costs (f)</td><td>279.4</td><td>207.9</td><td>159.5</td><td>126.9</td><td>114.5</td><td>711.6</td><td>1,599.8</td></tr><tr><td>Total (g)</td><td>$ 424.6</td><td>$ 613.3</td><td>$ 606.9</td><td>$ 503.4</td><td>$ 218.8</td><td>$ 4,107.7</td><td>$ 6,474.7</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 2015 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 Eversource’s estimated pension contributions to its qualified Pension Plan. Contributions in 2017 through 2020 and thereafter will vary depending on many factors, including the performance of existing plan assets, valuation of the plan’s liabilities and long-term discount rates, and are subject to change.

(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 the Access Northeast project or for a contingent commitment of approximately $20 million to an energy investment fund, which would be invested under certain conditions, 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 12, “Leases,” to the financial statements.



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, 2015, 2014, and 2013 included in this Annual Report on Form 10-K.

Comparison of 2015 to 2014:

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">Increase/</td></tr><tr><td>2015</td><td>2014</td><td>(Decrease)</td><td>Percent</td><td></td></tr><tr><td>Operating Revenues</td><td>$ 7,954.8</td><td>$ 7,741.9</td><td>$ 212.9</td><td>2.7%</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>3,086.9</td><td>3,021.6</td><td>65.3</td><td>2.2</td><td></td></tr><tr><td>Operations and Maintenance</td><td>1,329.3</td><td>1,427.6</td><td>(98.3)</td><td>(6.9)</td><td></td></tr><tr><td>Depreciation</td><td>665.9</td><td>614.7</td><td>51.2</td><td>8.3</td><td></td></tr><tr><td>Amortization of Regulatory Assets, Net</td><td>22.3</td><td>10.7</td><td>11.6</td><td>(a)</td><td></td></tr><tr><td>Energy Efficiency Programs</td><td>495.7</td><td>473.1</td><td>22.6</td><td>4.8</td><td></td></tr><tr><td>Taxes Other Than Income Taxes</td><td>590.5</td><td>561.4</td><td>29.1</td><td>5.2</td><td></td></tr><tr><td>Total Operating Expenses</td><td>6,190.6</td><td>6,109.1</td><td>81.5</td><td>1.3</td><td></td></tr><tr><td>Operating Income</td><td>1,764.2</td><td>1,632.8</td><td>131.4</td><td>8.0</td><td></td></tr><tr><td>Interest Expense</td><td>372.4</td><td>362.1</td><td>10.3</td><td>2.8</td><td></td></tr><tr><td>Other Income, Net</td><td>34.2</td><td>24.6</td><td>9.6</td><td>39.0</td><td></td></tr><tr><td>Income Before Income Tax Expense</td><td>1,426.0</td><td>1,295.3</td><td>130.7</td><td>10.1</td><td></td></tr><tr><td>Income Tax Expense</td><td>540.0</td><td>468.3</td><td>71.7</td><td>15.3</td><td></td></tr><tr><td>Net Income</td><td>886.0</td><td>827.0</td><td>59.0</td><td>7.1</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>$ 878.5</td><td>$ 819.5</td><td>$ 59.0</td><td>7.2%</td><td></td></tr></table>

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

Operating Revenues

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">Increase /</td></tr><tr><td>2015</td><td>2014</td><td>(Decrease)</td><td>Percent</td><td></td></tr><tr><td>Electric Distribution</td><td>$ 5,903.6</td><td>$ 5,663.4</td><td>$ 240.2</td><td>4.2%</td><td></td></tr><tr><td>Natural Gas Distribution</td><td>995.5</td><td>1,007.3</td><td>(11.8)</td><td>(1.2)</td><td></td></tr><tr><td>Electric Transmission</td><td>1,069.1</td><td>1,018.2</td><td>50.9</td><td>5.0</td><td></td></tr><tr><td>Other and Eliminations</td><td>(13.4)</td><td>53.0</td><td>(66.4)</td><td>(a)</td><td></td></tr><tr><td>Total Operating Revenues</td><td>$ 7,954.8</td><td>$ 7,741.9</td><td>$ 212.9</td><td>2.7%</td><td></td></tr></table>

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

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

For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="5">Increase/</td></tr><tr><td>2015</td><td>2014</td><td>(Decrease)</td><td>Percent</td><td></td></tr><tr><td>Electric Sales Volumes in GWh:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Traditional</td><td>28,982</td><td>28,811</td><td>171</td><td>0.6%</td><td></td></tr><tr><td>Decoupled</td><td>25,634</td><td>25,631</td><td>3</td><td>-</td><td></td></tr><tr><td>Total Electric Sales Volumes in GWh</td><td>54,616</td><td>54,442</td><td>174</td><td>0.3%</td><td></td></tr><tr><td>Firm Natural Gas Sales Volumes in Million Cubic Feet</td><td>102,999</td><td>104,191</td><td>(1,192)</td><td>(1.1)%</td><td></td></tr></table>

Operating Revenues, which primarily consist of base electric and natural gas distribution revenues and tracked revenues further described below, increased by $212.9 million in the aggregate in 2015 compared to 2014.

Base electric and natural gas distribution revenues: Base electric distribution segment revenues increased $150.9 million due primarily to CL&P's base distribution rate increase, effective December 1, 2014 ($136.3 million) and higher retail sales volumes driven by weather impacts at our non-decoupled operating companies (traditional). In addition, Operating Revenues increased $19.9 million at CL&P due to the PURA-approved settlement agreement regarding ADIT, $11 million for the Comprehensive Settlement Agreement associated with the recovery of LBR related to 2009 through 2011 energy efficiency programs at NSTAR Electric, and $20.7 million increase of 2015 LBR recognition at NSTAR Electric compared to 2014 LBR amounts. The $19.9 million represents CL&P's revenue requirement from the settlement agreement's rate increase through December 31, 2015, and is being collected from customers in rates over a 24-month period beginning December 1, 2015. The impact of colder winter weather experienced in the first quarter of 2015 and warmer weather in the third quarter of 2015, partially offset by milder winter weather in the fourth quarter of 2015, all as compared to the same periods in 2014, were the primary drivers of the increase in 2015 retail electric sales volumes of 0.6 percent and base electric distribution revenues at NSTAR Electric and PSNH.

For CL&P (effective December 1, 2014) and WMECO, fluctuations in retail electric sales volumes do not impact 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. Therefore, changes in sales volumes had no impact on the level of base distribution revenue realized at our decoupled companies.

Firm natural gas base distribution segment revenues decreased $4.9 million due primarily to a 1.1 percent decrease in firm natural gas sales volumes in 2015, as compared to 2014. This was due to record warm weather in the fourth quarter of 2015 when compared to 2014, partially offset by colder winter weather in the first quarter of 2015 compared to 2014. Weather-normalized firm natural gas sales volumes (based on 30-year average temperatures) increased 2.5 percent in 2015 compared to 2014, due primarily to improved economic conditions as well as residential and commercial customer growth, partially offset by the impact of customer conservation efforts resulting from company-sponsored energy efficiency programs.

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. Tracked electric distribution segment revenues increased primarily as a result of increases in energy supply costs ($176.4 million), driven by increased average retail rates, and increases in energy efficiency program revenues ($18.3 million). These increases were partially offset by a decrease in retail electric transmission charges ($77.5 million) and a decrease in the federally mandated congestion charge primarily driven by refunds in 2015 for a prior year overrecovery ($103.9 million). Tracked natural gas supply revenues decreased $20.1 million as a result of a decrease in average rates related to the recovery of natural gas supply costs.

Electric transmission revenues: The electric transmission segment revenues increased by $50.9 million due primarily to the result of lower reserves associated with the FERC ROE complaint proceedings in 2015 compared to 2014 and higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Other: Other revenues decreased due primarily to the sale of Eversource’s unregulated contracting business on April 13, 2015 ($55 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 reconciling cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power, Fuel and Transmission increased in 2015, as compared to 2014, due primarily to the following:

<table><tr><td>(Millions of Dollars)</td><td>Increase/(Decrease)</td></tr><tr><td>Electric Distribution</td><td>$ 74.8</td></tr><tr><td>Natural Gas Distribution</td><td>(1.6)</td></tr><tr><td>Electric Transmission</td><td>2.8</td></tr><tr><td>Other and Eliminations</td><td>(10.7)</td></tr><tr><td>Total Purchased Power, Fuel and Transmission</td><td>$ 65.3</td></tr></table>

The increase in purchased power costs at the electric distribution business was driven by higher prices associated with the procurement of energy supply in 2015, as compared to 2014. The decrease in purchased power costs at the natural gas distribution business was due to lower average natural gas prices in 2015, as compared to 2014.

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 decreased in 2015, as compared to 2014, 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>Resolution of basic service bad debt adder mechanism at NSTAR Electric</td><td>$ (24.2)</td></tr><tr><td>Contribution to create clean energy fund in connection with the generation divestiture agreement at PSNH</td><td>5.0</td></tr><tr><td>Increase in employee-related expenses, including labor and benefits</td><td>1.8</td></tr><tr><td>Other operations and maintenance</td><td>7.0</td></tr><tr><td>Total Base Electric Distribution</td><td>(10.4)</td></tr><tr><td>Total Base Natural Gas Distribution</td><td>(1.5)</td></tr><tr><td>Total Tracked costs (Transmission and Electric and Natural Gas Distribution)</td><td>(9.3)</td></tr><tr><td>Total Distribution and Transmission</td><td>(21.2)</td></tr><tr><td>Other and eliminations:</td><td></td></tr><tr><td>Integration costs</td><td>(8.4)</td></tr><tr><td>Absence of Eversource’s unregulated electrical contracting business due to sale in April 2015, net</td><td>(45.7)</td></tr><tr><td>Merger-related costs allowed for recovery</td><td>(7.0)</td></tr><tr><td>ES Parent and Other Companies</td><td>(16.0)</td></tr><tr><td>Total Operations and Maintenance</td><td>$ (98.3)</td></tr></table>

Depreciation increased in 2015, as compared to 2014, due primarily to higher utility plant in service balances resulting from completed construction projects placed into service and an increase in depreciation rates at CL&P as a result of the distribution rate case effective December 1, 2014.



Amortization of Regulatory Assets, Net, which are tracked costs, include certain regulatory-approved tracking mechanisms. Fluctuations in these costs are recovered from customers in rates and have no impact on earnings. Amortization of Regulatory Assets, Net, increased in 2015, as compared to 2014, due primarily to the following:

<table><tr><td>(Millions of Dollars)</td><td>Increase/(Decrease)</td></tr><tr><td>CL&amp;P:</td><td></td></tr><tr><td>Amortization increase (including storm cost recovery) approved and included in base distribution rates</td><td>$ 61.0</td></tr><tr><td>Energy and energy-related supply costs tracking mechanism</td><td>(108.0)</td></tr><tr><td>NSTAR Electric (primarily the recognition of the Comprehensive Settlement Agreement, partially offset by transition costs tracking mechanism)</td><td>(6.7)</td></tr><tr><td>PSNH (primarily default energy service charge tracking mechanism)</td><td>45.9</td></tr><tr><td>WMECO (primarily the absence of the refund of DOE proceeds to customers in 2014 and energy and energy-related cost tracking mechanisms)</td><td>20.7</td></tr><tr><td>Other</td><td>(1.3)</td></tr><tr><td>Total Amortization of Regulatory Assets, Net</td><td>$ 11.6</td></tr></table>

The increase in CL&P’s amortization was due primarily to an increase in storm cost recovery, which was approved and included in distribution rates effective December 1, 2014. In connection with the Comprehensive Settlement Agreement associated with the CPSL program filings, NSTAR Electric recognized an $11.7 million benefit in the first quarter of 2015, which was recorded as a reduction to amortization expense.

The remaining fluctuations in amortization expense are driven by the deferral of energy supply and energy-related costs, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. Fluctuations in energy supply and energy-related costs, which are the primary drivers in amortization, are recovered from customers in rates and have no impact on earnings.

Energy Efficiency Programs, which are tracked costs, increased in 2015, as compared to 2014, due primarily to an increase in energy efficiency costs in accordance with the three-year program guidelines established by the DPU at NSTAR Electric.

Taxes Other Than Income Taxes increased in 2015, as compared to 2014, due primarily to an increase in property taxes as a result of both an increase in utility plant balances and property tax rates.

Interest Expense increased in 2015, as compared to 2014, due primarily to an increase in interest on long-term debt ($9.3 million) as a result of new debt issuances in 2015 and an increase in interest on notes payable ($1.9 million).

Other Income, Net increased in 2015, as compared to 2014, due primarily to higher equity AFUDC amounts ($5.1 million) and an increase in interest income related to the deferred compensation plans ($4.3 million), partially offset by the absence in 2015 of a gain on the sale of land recorded in 2014 at CL&P ($4.5 million).

Income Tax Expense increased in 2015, as compared to 2014, due primarily to higher pre-tax earnings ($45.7 million), higher state taxes, the impact of adjusting our estimated tax expense to what was filed on our tax return (provision to return), the lower tax benefit in 2015 compared to 2014 from a change in tax reserves ($19.8 million), and higher items that impact our tax rate as a result of regulatory treatment (flow-through items) ($6.2 million).



<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2014</td><td>2013</td><td>Increase/ (Decrease)</td><td>Percent</td></tr><tr><td>Operating Revenues</td><td>$ 7,741.9</td><td>$ 7,301.2</td><td>$ 440.7</td><td>6.0%</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>3,021.6</td><td>2,483.0</td><td>538.6</td><td>21.7</td></tr><tr><td>Operations and Maintenance</td><td>1,427.6</td><td>1,515.0</td><td>(87.4)</td><td>(5.8)</td></tr><tr><td>Depreciation</td><td>614.7</td><td>610.8</td><td>3.9</td><td>0.6</td></tr><tr><td>Amortization of Regulatory Assets, Net</td><td>10.7</td><td>206.3</td><td>(195.6)</td><td>(94.8)</td></tr><tr><td>Amortization of Rate Reduction Bonds</td><td>-</td><td>42.6</td><td>(42.6)</td><td>(100.0)</td></tr><tr><td>Energy Efficiency Programs</td><td>473.1</td><td>401.9</td><td>71.2</td><td>17.7</td></tr><tr><td>Taxes Other Than Income Taxes</td><td>561.4</td><td>512.2</td><td>49.2</td><td>9.6</td></tr><tr><td>Total Operating Expenses</td><td>6,109.1</td><td>5,771.8</td><td>337.3</td><td>5.8</td></tr><tr><td>Operating Income</td><td>1,632.8</td><td>1,529.4</td><td>103.4</td><td>6.8</td></tr><tr><td>Interest Expense</td><td>362.1</td><td>338.7</td><td>23.4</td><td>6.9</td></tr><tr><td>Other Income, Net</td><td>24.6</td><td>29.9</td><td>(5.3)</td><td>(17.7)</td></tr><tr><td>Income Before Income Tax Expense</td><td>1,295.3</td><td>1,220.6</td><td>74.7</td><td>6.1</td></tr><tr><td>Income Tax Expense</td><td>468.3</td><td>426.9</td><td>41.4</td><td>9.7</td></tr><tr><td>Net Income</td><td>827.0</td><td>793.7</td><td>33.3</td><td>4.2</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>7.5</td><td>7.7</td><td>(0.2)</td><td>(2.6)</td></tr><tr><td>Net Income Attributable to Controlling Interest</td><td>$ 819.5</td><td>$ 786.0</td><td>$ 33.5</td><td>4.3%</td></tr></table>

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2014</td><td>2013</td><td>Increase / (Decrease)</td><td>Percent</td></tr><tr><td>Electric Distribution</td><td>$ 5,663.4</td><td>$ 5,362.3</td><td>$ 301.1</td><td>5.6%</td></tr><tr><td>Natural Gas Distribution</td><td>1,007.3</td><td>855.8</td><td>151.5</td><td>17.7</td></tr><tr><td>Transmission</td><td>1,018.2</td><td>978.7</td><td>39.5</td><td>4.0</td></tr><tr><td>Other and Eliminations</td><td>53.0</td><td>104.4</td><td>(51.4)</td><td>(49.2)</td></tr><tr><td>Total Operating Revenues</td><td>$ 7,741.9</td><td>$ 7,301.2</td><td>$ 440.7</td><td>6.0%</td></tr></table>

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

<table><tr><td rowspan="2"></td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2014</td><td>2013</td><td>Increase/ (Decrease)</td><td>Percent</td></tr><tr><td>Retail Electric Sales Volumes in GWh</td><td>54,442</td><td>55,331</td><td>(889)</td><td>(1.6)%</td></tr><tr><td>Firm Natural Gas Sales Volumes in Million Cubic Feet</td><td>104,191</td><td>98,258</td><td>5,933</td><td>6.0</td></tr></table>

Operating Revenues increased $440.7 million in 2014 compared to 2013.

The most significant factor in the increase in revenues relates to cost tracking mechanisms for the recovery of higher costs associated with the procurement of energy supply, which increased $506.8 million and $126.9 million for electric distribution and natural gas distribution, respectively. These costs were impacted by the overall New England wholesale energy supply market in which higher natural gas delivery costs had an adverse impact on the cost of electric energy purchased for our retail electric customers and the cost of natural gas purchased on behalf of our retail natural gas customers. Energy supply costs are recovered from customers in rates through cost tracking mechanisms and therefore have no impact on earnings. These costs and related recovery impacts were partially offset by decreases in transition cost recovery revenues, which are recovered through cost tracking mechanisms, reflecting the full collection in 2013 of previously deferred costs, as well as the full amortization of RRBs.

Firm base natural gas distribution revenues increased $26.3 million in 2014, as compared to 2013, which reflected a 6 percent increase in firm natural gas sales volumes. The increase in sales volumes was driven primarily by the colder winter weather experienced throughout our service territories in the first quarter of 2014. The weather conditions experienced were significantly colder than both normal and the same period last year throughout New England and our service territories in Connecticut and Massachusetts. Weather-normalized total firm natural gas sales volumes (based on 30-year average temperatures) increased 2.9 percent in 2014, as compared to 2013, due primarily to residential and commercial customer growth.

Base electric distribution revenues decreased $12.1 million in 2014 compared to 2013. This reflected the impact of a 1.6 percent decrease in retail electric sales volumes. The decrease in sales volumes was driven primarily by the cooler summer weather in 2014 compared to 2013, as well as the impact of our utility-sponsored energy efficiency programs. Weather-normalized retail electric sales volumes decreased 1 percent in 2014, as compared to 2013, reflecting the impact of our utility-sponsored energy efficiency programs. The negative sales volume impact was partially offset by the impact of CL&P's base distribution rate increase effective December 1, 2014.



CL&P and NSTAR Electric recognized lost base revenue (LBR) related to reductions in sales volume as a result of energy efficiency. LBR is recovered from retail distribution customers. Including the impact from the recognition of LBR, base distribution revenues increased in 2014, as compared to 2013. We recognized $45.2 million of LBR in 2014, compared to $20.3 million in 2013. Effective December 1, 2014, CL&P no longer recognizes LBR due to its revenue decoupling mechanism, which, similar to WMECO's revenue decoupling mechanism, provides a base amount of distribution revenues ($1.059 billion on an annual basis) that effectively breaks the relationship between revenues and customer electricity usage. The revenue decoupling mechanism is designed to allow each of CL&P and WMECO to encourage energy efficiency for its customers without negatively impacting its revenues.

Transmission revenues increased $39.5 million in 2014, as compared to 2013, due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure. This increase was partially offset by the impact of the $37 million net reserve recorded in 2014 as a result of the 2014 FERC ROE orders, compared to the $23.7 million reserve recorded in 2013 for the FERC ALJ initial decision in the FERC base ROE complaints.

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 reconciling cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power, Fuel and Transmission increased in 2014, as compared to 2013, due primarily to the following:

<table><tr><td>(Millions of Dollars)</td><td>Increase/(Decrease)</td></tr><tr><td>Electric Distribution</td><td>$ 458.2</td></tr><tr><td>Natural Gas Distribution</td><td>104.1</td></tr><tr><td>Transmission</td><td>(2.8)</td></tr><tr><td>Other and Eliminations</td><td>(20.9)</td></tr><tr><td>Total Purchased Power, Fuel and Transmission</td><td>$ 538.6</td></tr></table>

The increase in purchased power, fuel and transmission at the electric and natural gas distribution businesses were driven by the higher costs associated with the procurement of energy supply. As a result of increases in the New England wholesale energy supply market for both electricity and natural gas, the costs incurred to purchase energy on behalf of our customers were significantly higher in 2014 compared to 2013. Our energy supply costs were impacted by higher natural gas delivery costs, which had an adverse impact on the cost of electric energy purchased for our retail electric customers and the cost of natural gas purchased on behalf of our retail natural gas customers.

Operations and Maintenance expense includes tracked costs and costs that are recovered through base electric and natural gas distribution rates, which therefore impact earnings (non-tracked costs). Operations and Maintenance decreased in 2014, as compared to 2013, 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>Labor and other employee-related costs, including pension costs</td><td>$ (77.3)</td></tr><tr><td>Implementation of a new outage restoration program at CL&amp;P</td><td>9.2</td></tr><tr><td>Storm restoration costs</td><td>(11.4)</td></tr><tr><td>All other operations and maintenance</td><td>(29.4)</td></tr><tr><td>Total Base Electric Distribution</td><td>(108.9)</td></tr><tr><td>Total Base Natural Gas Distribution</td><td>(0.9)</td></tr><tr><td>Total Tracked costs (Transmission and Electric and Natural Gas Distribution)</td><td>16.6</td></tr><tr><td>Total Distribution and Transmission</td><td>(93.2)</td></tr><tr><td>Other and eliminations:</td><td></td></tr><tr><td>Integration and severance costs</td><td>13.3</td></tr><tr><td>All other (including eliminations)</td><td>(7.5)</td></tr><tr><td>Total Operations and Maintenance</td><td>$ (87.4)</td></tr></table>

Depreciation increased in 2014, as compared to 2013, due primarily to an increase related to higher utility plant balances resulting from completed construction projects placed into service ($34.5 million), partially offset by a decrease in the CYAPC and YAEC decommissioning costs, which do not impact earnings ($30.6 million).

Amortization of Regulatory Assets, Net, which are tracked costs, include certain regulatory-approved tracking mechanisms. Fluctuations in these costs are recovered from customers in rates and have no impact on earnings. Amortization of Regulatory Assets, Net, decreased in 2014, as compared to 2013, due primarily to the following:

<table><tr><td>(Millions of Dollars)</td><td>Increase/(Decrease)</td></tr><tr><td>NSTAR Electric (primarily recovery of transition costs)</td><td>$ (236.4)</td></tr><tr><td>PSNH (primarily default energy service charge)</td><td>(9.2)</td></tr><tr><td>CL&amp;P (primarily energy supply and energy-related costs)</td><td>54.4</td></tr><tr><td>WMECO (primarily recovery of transition costs)</td><td>(3.0)</td></tr><tr><td>Other</td><td>(1.4)</td></tr><tr><td>Total Amortization of Regulatory Assets, Net</td><td>$ (195.6)</td></tr></table>

Amortization of Rate Reduction Bonds decreased in 2014, as compared to 2013, due to the maturity in 2013 of RRBs of NSTAR Electric, PSNH and WMECO.



Energy Efficiency Programs, which are tracked costs, increased in 2014, as compared to 2013, due primarily to the expanded energy conservation programs at CL&P in 2014 as a result of 2013 legislative action, and an increase in energy efficiency costs in accordance with the three-year program guidelines established by the DPU at NSTAR Electric and WMECO, partially offset by a decrease in the amortization of previously deferred costs at NSTAR Electric.

Taxes Other Than Income Taxes increased in 2014, as compared to 2013, due primarily to an increase in property taxes as a result of both an increase in utility plant balances and property tax rates.

Interest Expense increased in 2014, as compared to 2013, due primarily to lower interest income related to a decrease in the recovery of previously deferred transition costs ($9.9 million), an increase in interest on long-term debt ($4 million) as a result of new debt issuances in 2014 and the absence in 2014 of the favorable impact from the resolution of a Connecticut state income tax audit in 2013.

Other Income, Net decreased in 2014, as compared to 2013, due primarily to lower unrealized gains on the assets supporting the deferred compensation plans ($13 million), and the absence in 2014 of an insurance policy claim received in 2013 ($1.5 million), partially offset by higher AFUDC related to equity funds ($6.6 million), and a net gain on the sale of land ($4.5 million).

Income Tax Expense increased in 2014, as compared to 2013, due primarily to higher pre-tax earnings ($26.1 million), and higher state taxes and various other impacts ($15.3 million). The higher state taxes include a net reduction in the valuation allowance for state tax positions, which is based on the most recent available data.

## EARNINGS SUMMARY

Excluding the impact of integration costs, our 2014 earnings increased by $41.8 million, as compared to 2013. The increase was due primarily to lower operations and maintenance costs that impact earnings, which were primarily driven by lower labor and other employee-related costs, including approximately $30 million of non-tracked pension costs, and lower storm restoration costs, as well as higher firm natural gas sales volumes as a result of the colder weather in the first quarter of 2014, as compared to the first quarter of 2013. Partially offsetting this increase was the absence in 2014 of a favorable impact from the resolution of a state income tax audit in 2013, higher property taxes, higher depreciation expense at our regulated companies, and lower retail electric sales volumes as a result of cooler summer weather in 2014, as compared to the same period in 2013. Earnings were also unfavorably impacted by the 2014 after-tax net reserve of $22.4 million related to the 2014 FERC ROE orders, as compared to the 2013 after-tax reserve of $14.3 million related to the 2013 FERC ALJ initial decision in the FERC base ROE complaints.

Our electric distribution segment earnings increased $35.4 million in 2014, as compared to 2013, due primarily to lower operations and maintenance costs that impact earnings, which were primarily driven by lower labor and other employee-related costs, including pension costs, and lower storm restoration costs. Partially offsetting these favorable earnings impacts, as compared to 2013, were higher property taxes and depreciation expense, lower retail electric sales volumes as a result of cooler summer weather in 2014, and the absence in 2014 of regulatory interest income on stranded cost deferrals in 2013.

Our transmission segment earnings increased $8.4 million in 2014, as compared to 2013, due primarily to a decrease in transmission segment state income tax expense and a higher transmission rate base as a result of an increased investment in our transmission infrastructure. These favorable impacts were partially offset by the after-tax net reserve of $22.4 million related to the 2014 FERC ROE orders, as compared to the $14.3 million after-tax reserve related to the 2013 FERC ALJ initial decision in the FERC base ROE complaints.

Our natural gas distribution segment earnings increased $11.4 million in 2014, as compared to 2013, due primarily to higher firm natural gas sales volumes and peak demand revenues resulting from colder weather in the first quarter of 2014 and additional natural gas heating customers.

ES parent and other companies, which include our unregulated businesses, had a net loss of $10.6 million in 2014, compared with earnings of $11.1 million in 2013. Excluding the impact of integration costs, ES parent and other companies earned $11.5 million in 2014, compared with $24.9 million in 2013. The earnings decrease in 2014 was due primarily to a higher effective tax rate.

## LIQUIDITY

Cash flows provided by operating activities totaled $1.64 billion in 2014, compared with $1.66 billion in 2013. The 2014 operating cash flows were favorably impacted by approximately $132 million in DOE Damages proceeds resulting from the spent nuclear fuel litigation received by CL&P, NSTAR Electric, PSNH and WMECO from the Yankee Companies, the absence of 2013 cash disbursements for major storm restoration costs, the decrease of approximately $130 million in Pension and PBOP Plan cash contributions and changes in the timing of working capital items. These favorable impacts were more than offset by higher income tax payments in 2014 and the unfavorable cash flow impact resulting from lower recoveries from customers in 2014, as compared to 2013, relating to regulatory cost recovery tracking mechanisms. For further information on the spent nuclear fuel litigation, see Note 11C, “Commitments and Contingencies – Contractual Obligations – Yankee Companies,” in this combined Annual Report on Form 10-K.

Results of Operations for each of CL&P, NSTAR Electric, PSNH and WMECO have been omitted from this report but are set forth in the Annual Report on Form 10-K for 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. 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, 2015, approximately 95 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 $4.7 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, 2015, our Regulated companies did not hold collateral (letters of credit) from counterparties related to our standard service contracts. As of December 31, 2015, Eversource had $17.1 million of cash posted with ISO-NE related to energy purchase transactions.

For further information on cash collateral deposited and posted with counterparties, see Note 1G, “Summary of Significant Accounting Policies - Deposits,” and Note 4, “Derivative Instruments,” 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, 2015.

February 26, 2016



## REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Trustees and Shareholders of Eversource Energy:

We have audited the accompanying consolidated balance sheets of Eversource Energy and subsidiaries (the "Company") as of December 31, 2015 and 2014, and 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, 2015. Our audits also included the financial statement schedules listed in the Index at Item 15 of Part IV. We also have audited the Company's internal control over financial reporting as of December 31, 2015, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company's management is responsible for these financial statements and financial statement schedules, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Company Report on Internal Controls Over Financial Reporting. Our responsibility is to express an opinion on these financial statements and financial statement schedules and an opinion on the Company's internal control over financial reporting based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel 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 the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Eversource Energy and subsidiaries as of December 31, 2015 and 2014, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2015, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein. Also, in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2015, based on the criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

/s/ Deloitte & Touche LLP

Hartford, Connecticut
February 26, 2016



<table><tr><td>(Thousands of Dollars)</td><td>2015</td><td>As of December 31, 2014</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>$ 23,947</td><td>$ 38,703</td></tr><tr><td>Receivables, Net</td><td>775,480</td><td>856,346</td></tr><tr><td>Unbilled Revenues</td><td>202,647</td><td>211,758</td></tr><tr><td>Taxes Receivable</td><td>305,359</td><td>337,307</td></tr><tr><td>Fuel, Materials and Supplies</td><td>336,476</td><td>349,664</td></tr><tr><td>Regulatory Assets</td><td>845,843</td><td>672,493</td></tr><tr><td>Prepayments and Other Current Assets</td><td>129,034</td><td>226,194</td></tr><tr><td>Total Current Assets</td><td>2,618,786</td><td>2,692,465</td></tr><tr><td>Property, Plant and Equipment, Net</td><td>19,892,441</td><td>18,647,041</td></tr><tr><td>Deferred Debits and Other Assets:</td><td></td><td></td></tr><tr><td>Regulatory Assets</td><td>3,737,960</td><td>4,054,086</td></tr><tr><td>Goodwill</td><td>3,519,401</td><td>3,519,401</td></tr><tr><td>Marketable Securities</td><td>516,478</td><td>515,025</td></tr><tr><td>Other Long-Term Assets</td><td>295,243</td><td>312,369</td></tr><tr><td>Total Deferred Debits and Other Assets</td><td>8,069,082</td><td>8,400,881</td></tr><tr><td>Total Assets</td><td>$ 30,580,309</td><td>$ 29,740,387</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>$ 1,160,953</td><td>$ 956,825</td></tr><tr><td>Long-Term Debt - Current Portion</td><td>228,883</td><td>245,583</td></tr><tr><td>Accounts Payable</td><td>813,646</td><td>868,231</td></tr><tr><td>Regulatory Liabilities</td><td>107,759</td><td>235,022</td></tr><tr><td>Accumulated Deferred Income Taxes</td><td>-</td><td>160,288</td></tr><tr><td>Other Current Liabilities</td><td>678,549</td><td>668,432</td></tr><tr><td>Total Current Liabilities</td><td>2,989,790</td><td>3,134,381</td></tr><tr><td>Deferred Credits and Other Liabilities:</td><td></td><td></td></tr><tr><td>Accumulated Deferred Income Taxes</td><td>5,147,678</td><td>4,467,473</td></tr><tr><td>Regulatory Liabilities</td><td>513,595</td><td>515,144</td></tr><tr><td>Derivative Liabilities</td><td>337,102</td><td>409,632</td></tr><tr><td>Accrued Pension, SERP and PBOP</td><td>1,407,288</td><td>1,638,558</td></tr><tr><td>Other Long-Term Liabilities</td><td>871,499</td><td>874,387</td></tr><tr><td>Total Deferred Credits and Other Liabilities</td><td>8,277,162</td><td>7,905,194</td></tr><tr><td>Capitalization:</td><td></td><td></td></tr><tr><td>Long-Term Debt</td><td>8,805,574</td><td>8,568,429</td></tr><tr><td>Noncontrolling Interest - Preferred Stock of Subsidiaries</td><td>155,568</td><td>155,568</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>1,669,313</td><td>1,666,796</td></tr><tr><td>Capital Surplus, Paid In</td><td>6,262,368</td><td>6,235,834</td></tr><tr><td>Retained Earnings</td><td>2,797,355</td><td>2,448,661</td></tr><tr><td>Accumulated Other Comprehensive Loss</td><td>(66,844)</td><td>(74,009)</td></tr><tr><td>Treasury Stock</td><td>(309,977)</td><td>(300,467)</td></tr><tr><td>Common Shareholders&#x27; Equity</td><td>10,352,215</td><td>9,976,815</td></tr><tr><td>Total Capitalization</td><td>19,313,357</td><td>18,700,812</td></tr><tr><td>Commitments and Contingencies (Note 11)</td><td></td><td></td></tr><tr><td>Total Liabilities and Capitalization</td><td>$ 30,580,309</td><td>$ 29,740,387</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 rowspan="2">2015</td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td>2014</td><td>2013</td><td></td></tr><tr><td>Operating Revenues</td><td>$ 7,954,827</td><td>$ 7,741,856</td><td>$ 7,301,204</td><td></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>3,086,905</td><td>3,021,550</td><td>2,482,954</td><td></td></tr><tr><td>Operations and Maintenance</td><td>1,329,289</td><td>1,427,589</td><td>1,514,986</td><td></td></tr><tr><td>Depreciation</td><td>665,856</td><td>614,657</td><td>610,777</td><td></td></tr><tr><td>Amortization of Regulatory Assets, Net</td><td>22,339</td><td>10,704</td><td>206,322</td><td></td></tr><tr><td>Amortization of Rate Reduction Bonds</td><td>-</td><td>-</td><td>42,581</td><td></td></tr><tr><td>Energy Efficiency Programs</td><td>495,701</td><td>473,127</td><td>401,919</td><td></td></tr><tr><td>Taxes Other Than Income Taxes</td><td>590,573</td><td>561,380</td><td>512,230</td><td></td></tr><tr><td>Total Operating Expenses</td><td>6,190,663</td><td>6,109,007</td><td>5,771,769</td><td></td></tr><tr><td>Operating Income</td><td>1,764,164</td><td>1,632,849</td><td>1,529,435</td><td></td></tr><tr><td>Interest Expense</td><td>372,420</td><td>362,106</td><td>338,699</td><td></td></tr><tr><td>Other Income, Net</td><td>34,227</td><td>24,619</td><td>29,894</td><td></td></tr><tr><td>Income Before Income Tax Expense</td><td>1,425,971</td><td>1,295,362</td><td>1,220,630</td><td></td></tr><tr><td>Income Tax Expense</td><td>539,967</td><td>468,297</td><td>426,941</td><td></td></tr><tr><td>Net Income</td><td>886,004</td><td>827,065</td><td>793,689</td><td></td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>7,519</td><td>7,519</td><td>7,682</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 878,485</td><td>$ 819,546</td><td>$ 786,007</td><td></td></tr><tr><td>Basic Earnings Per Common Share</td><td>$ 2.77</td><td>$ 2.59</td><td>$ 2.49</td><td></td></tr><tr><td>Diluted Earnings Per Common Share</td><td>$ 2.76</td><td>$ 2.58</td><td>$ 2.49</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>317,336,881</td><td>316,136,748</td><td>315,311,387</td><td></td></tr><tr><td>Diluted</td><td>318,432,687</td><td>317,417,414</td><td>316,211,160</td><td></td></tr></table>

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

## CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

<table><tr><td>Net Income</td><td>$ 886,004</td><td>$ 827,065</td><td>$ 793,689</td></tr><tr><td>Other Comprehensive Income/(Loss), Net of Tax:</td><td></td><td></td><td></td></tr><tr><td>Qualified Cash Flow Hedging Instruments</td><td>2,079</td><td>2,037</td><td>2,049</td></tr><tr><td>Changes in Unrealized (Losses)/Gains on Marketable Securities</td><td>(2,588)</td><td>315</td><td>(940)</td></tr><tr><td>Changes in Funded Status of Pension, SERP and PBOP Benefit Plans</td><td>7,674</td><td>(30,330)</td><td>25,714</td></tr><tr><td>Other Comprehensive Income/(Loss), Net of Tax</td><td>7,165</td><td>(27,978)</td><td>26,823</td></tr><tr><td>Comprehensive Income Attributable to Noncontrolling Interests</td><td>(7,519)</td><td>(7,519)</td><td>(7,682)</td></tr><tr><td>Comprehensive Income Attributable to Common Shareholders</td><td>$ 885,650</td><td>$ 791,568</td><td>$ 812,830</td></tr></table>

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



<table><tr><td>(Thousands of Dollars, Except Share Information)</td><td colspan="2">Common Shares</td><td>Capital Surplus, Paid In</td><td>Retained Earnings</td><td>Accumulated Other Comprehensive Income/(Loss)</td><td>Treasury Stock</td><td>Total Common Shareholders&#x27; Equity</td></tr><tr><td>Balance as of January 1, 2013</td><td>314,053,634</td><td>$ 1,662,547</td><td>$ 6,183,267</td><td>$ 1,802,714</td><td>$ (72,854)</td><td>$ (338,624)</td><td>$ 9,237,050</td></tr><tr><td>Net Income</td><td></td><td></td><td></td><td>793,689</td><td></td><td></td><td>793,689</td></tr><tr><td>Dividends on Common Shares - $1.47 Per Share</td><td></td><td></td><td></td><td>(462,741)</td><td></td><td></td><td>(462,741)</td></tr><tr><td>Dividends on Preferred Stock</td><td></td><td></td><td></td><td>(7,682)</td><td></td><td></td><td>(7,682)</td></tr><tr><td>Issuance of Common Shares, $5 Par Value</td><td>560,848</td><td>2,804</td><td>8,274</td><td></td><td></td><td></td><td>11,078</td></tr><tr><td>Long-Term Incentive Plan Activity</td><td></td><td></td><td>(10,748)</td><td></td><td></td><td></td><td>(10,748)</td></tr><tr><td>Issuance of Treasury Shares</td><td>659,077</td><td></td><td>17,381</td><td></td><td></td><td>12,087</td><td>29,468</td></tr><tr><td>Other Changes in Shareholders&#x27; Equity</td><td></td><td></td><td>(5,409)</td><td></td><td></td><td></td><td>(5,409)</td></tr><tr><td>Other Comprehensive Income</td><td></td><td></td><td></td><td>26,823</td><td></td><td></td><td>26,823</td></tr><tr><td>Balance as of December 31, 2013</td><td>315,273,559</td><td>1,665,351</td><td>6,192,765</td><td>2,125,980</td><td>(46,031)</td><td>(326,537)</td><td>9,611,528</td></tr><tr><td>Net Income</td><td></td><td></td><td></td><td>827,065</td><td></td><td></td><td>827,065</td></tr><tr><td>Dividends on Common Shares - $1.57 Per Share</td><td></td><td></td><td></td><td>(496,524)</td><td></td><td></td><td>(496,524)</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>288,941</td><td>1,445</td><td>5,164</td><td></td><td></td><td></td><td>6,609</td></tr><tr><td>Long-Term Incentive Plan Activity</td><td></td><td></td><td>(9,569)</td><td></td><td></td><td></td><td>(9,569)</td></tr><tr><td>Issuance of Treasury Shares</td><td>1,420,837</td><td></td><td>37,817</td><td></td><td></td><td>26,070</td><td>63,887</td></tr><tr><td>Other Changes in Shareholders&#x27; Equity</td><td></td><td></td><td>9,657</td><td>(341)</td><td></td><td></td><td>9,316</td></tr><tr><td>Other Comprehensive Loss</td><td></td><td></td><td></td><td></td><td>(27,978)</td><td></td><td>(27,978)</td></tr><tr><td>Balance as of December 31, 2014</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></table>

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



<table><tr><td rowspan="2">(Thousands of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>Operating Activities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Income</td><td>$     886,004</td><td>$     827,065</td><td>$     793,689</td><td></td></tr><tr><td>Adjustments to Reconcile Net Income to Net Cash Flows</td><td></td><td></td><td></td><td></td></tr><tr><td>Provided by Operating Activities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Depreciation</td><td>665,856</td><td>614,657</td><td>610,777</td><td></td></tr><tr><td>Deferred Income Taxes</td><td>491,736</td><td>443,259</td><td>431,413</td><td></td></tr><tr><td>Pension, SERP and PBOP Expense</td><td>96,017</td><td>99,056</td><td>195,698</td><td></td></tr><tr><td>Pension and PBOP Contributions</td><td>(162,452)</td><td>(211,649)</td><td>(342,184)</td><td></td></tr><tr><td>Regulatory (Under)/Over Recoveries, Net</td><td>(163,287)</td><td>6,853</td><td>(24,276)</td><td></td></tr><tr><td>Amortization of Regulatory Assets, Net</td><td>22,339</td><td>10,704</td><td>206,322</td><td></td></tr><tr><td>Amortization of Rate Reduction Bonds</td><td>-</td><td>-</td><td>42,581</td><td></td></tr><tr><td>(Payments)/Refunds Related to Spent Nuclear Fuel, Net</td><td>(297,253)</td><td>132,138</td><td>-</td><td></td></tr><tr><td>Other</td><td>(91,945)</td><td>39,523</td><td>56,071</td><td></td></tr><tr><td>Changes in Current Assets and Liabilities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Receivables and Unbilled Revenues, Net</td><td>(39,797)</td><td>(122,139)</td><td>(163,549)</td><td></td></tr><tr><td>Fuel, Materials and Supplies</td><td>34,112</td><td>(41,310)</td><td>(14,811)</td><td></td></tr><tr><td>Taxes Receivable/Accrued, Net</td><td>30,282</td><td>(323,224)</td><td>(50,950)</td><td></td></tr><tr><td>Accounts Payable</td><td>(91,618)</td><td>144,743</td><td>(54,619)</td><td></td></tr><tr><td>Other Current Assets and Liabilities, Net</td><td>44,031</td><td>15,797</td><td>(22,623)</td><td></td></tr><tr><td>Net Cash Flows Provided by Operating Activities</td><td>1,424,025</td><td>1,635,473</td><td>1,663,539</td><td></td></tr><tr><td>Investing Activities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Investments in Property, Plant and Equipment</td><td>(1,724,139)</td><td>(1,603,744)</td><td>(1,456,787)</td><td></td></tr><tr><td>Proceeds from Sales of Marketable Securities</td><td>799,165</td><td>488,789</td><td>627,532</td><td></td></tr><tr><td>Purchases of Marketable Securities</td><td>(717,114)</td><td>(491,220)</td><td>(679,784)</td><td></td></tr><tr><td>Other Investing Activities</td><td>(17,062)</td><td>14,380</td><td>67,816</td><td></td></tr><tr><td>Net Cash Flows Used in Investing Activities</td><td>(1,659,150)</td><td>(1,591,795)</td><td>(1,441,223)</td><td></td></tr><tr><td>Financing Activities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Cash Dividends on Common Shares</td><td>(529,791)</td><td>(475,227)</td><td>(462,741)</td><td></td></tr><tr><td>Cash Dividends on Preferred Stock</td><td>(7,519)</td><td>(7,519)</td><td>(7,682)</td><td></td></tr><tr><td>(Decrease)/Increase in Short-Term Debt</td><td>(242,122)</td><td>285,075</td><td>(397,000)</td><td></td></tr><tr><td>Issuance of Long-Term Debt</td><td>1,225,000</td><td>725,000</td><td>1,680,000</td><td></td></tr><tr><td>Retirements of Long-Term Debt</td><td>(216,700)</td><td>(576,551)</td><td>(929,885)</td><td></td></tr><tr><td>Retirements of Rate Reduction Bonds</td><td>-</td><td>-</td><td>(82,139)</td><td></td></tr><tr><td>Other Financing Activities</td><td>(8,499)</td><td>883</td><td>(25,253)</td><td></td></tr><tr><td>Net Cash Flows Provided by/(Used in) Financing Activities</td><td>220,369</td><td>(48,339)</td><td>(224,700)</td><td></td></tr><tr><td>Net Decrease in Cash and Cash Equivalents</td><td>(14,756)</td><td>(4,661)</td><td>(2,384)</td><td></td></tr><tr><td>Cash and Cash Equivalents - Beginning of Year</td><td>38,703</td><td>43,364</td><td>45,748</td><td></td></tr><tr><td>Cash and Cash Equivalents - End of Year</td><td>$     23,947</td><td>$     38,703</td><td>$     43,364</td><td></td></tr></table>

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

The 2015 financial statements for CL&P, NSTAR Electric, PSNH and WMECO have been omitted from this report but are set forth in the Annual Report on Form 10-K for 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. 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
WESTERN MASSACHUSETTS ELECTRIC COMPANY

## 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, PSNH and WMECO

Eversource Energy: 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, PSNH, WMECO, Yankee Gas and NSTAR Gas. Eversource provides energy delivery service to approximately 3.6 million electric and natural gas customers through these six regulated utilities in Connecticut, Massachusetts and New Hampshire.

On April 30, 2015, the Company’s legal name was changed from Northeast Utilities to Eversource Energy. CL&P, NSTAR Electric, PSNH and WMECO are each doing business as Eversource Energy.

Eversource, CL&P, NSTAR Electric, PSNH and WMECO 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. The 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, WMECO and NSTAR Gas, and the NHPUC for PSNH).

Regulated Companies: CL&P, NSTAR Electric, PSNH and WMECO 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. CL&P, NSTAR Electric, PSNH and WMECO's results include the operations of their respective distribution and transmission businesses. PSNH and WMECO's distribution results include the operations of their respective generation businesses. 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.

Other: Eversource Service, Eversource’s service company, Rocky River Realty Company, a wholly-owned real estate subsidiary of Eversource, Renewable Properties, Inc., an indirect, wholly-owned subsidiary of Eversource, and Properties, Inc., a wholly-owned subsidiary of PSNH, provide support services to Eversource, including its Regulated companies. Eversource Gas Transmission LLC, an indirect, wholly-owned subsidiary of Eversource, holds an equity interest in the Access Northeast project.

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

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

Certain reclassifications of prior year data were made in the accompanying financial statements to conform to the current year presentation and as a result of the adoption of new accounting guidance. See Note 1C, “Summary of Significant Accounting Policies – Accounting Standards,” for further information.

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, 2015 and 2014, Eversource’s carrying amount of goodwill was approximately $3.5 billion. Eversource performs an assessment for possible impairment of its goodwill at least annually. Eversource completed its annual goodwill impairment test for each of its reporting units as of October 1, 2015 and determined that no impairment exists. See Note 21, “Goodwill,” for further information.

## C. Accounting Standards

Accounting Standards Issued but not Yet Effective: In May 2014, the Financial Accounting Standards Board (FASB) issued an Accounting Standards Update (ASU) 2014-09, Revenue from Contracts with Customers, which amends existing revenue recognition guidance and is required to be applied retrospectively (either to each reporting period presented or cumulatively at the date of initial application). In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers – Deferral of the Effective Date, which defers the effective date of ASU 2014-09 to the first quarter of 2018, with 2017 application permitted. The Company is reviewing the requirements of ASU 2014-09 and will implement the standard in the first quarter of 2018. The ASU is not expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

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 Company is reviewing the requirements of the ASU. The ASU will remove the available-for-sale designation for equity securities, whereby changes in fair value are recorded in other comprehensive income in 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, 2015 was approximately $52 million. 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, PSNH or WMECO.

On February 25, 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 is required to be implemented for leases beginning on the date of initial application. For prior periods presented, leases are required to be recognized and measured using a modified retrospective approach. The Company is reviewing the requirements of ASU 2016-02.

Recently Adopted Accounting Standards: In April 2015, the FASB issued ASU 2015-03, Simplifying the Presentation of Debt Issuance Costs, that changed the balance sheet presentation of debt issuance costs. Under the ASU, issuance costs related to debt are presented on the balance sheet as a direct deduction from the carrying amount of the debt liability rather than as a deferred cost. The new accounting guidance is effective for interim and annual periods beginning in the first quarter of 2016 with early adoption permitted and is required to be applied retrospectively. On December 31, 2015, the Company adopted the new accounting guidance and applied it retrospectively to all prior periods presented in the financial statements. The adoption of this ASU did not have a material effect on the balance sheets and had no impact on the results of operations or cash flows of Eversource, CL&P, NSTAR Electric, PSNH or WMECO. See Note 8, “Long-Term Debt,” for the prior year amounts that have been retrospectively adjusted.

On November 20, 2015, the FASB issued ASU 2015-17, Balance Sheet Classification of Deferred Taxes, that required all deferred tax liabilities and assets, along with any related valuation allowance, be classified as noncurrent on the balance sheet. This new accounting guidance is effective for interim and annual periods beginning in the first quarter of 2017 with early adoption permitted and may be applied either prospectively or retrospectively. On December 31, 2015, the Company adopted the new accounting guidance and applied it prospectively. The adoption of this ASU did not have a material effect on the balance sheets and had no impact on the results of operations or cash flows of Eversource, CL&P, NSTAR Electric, PSNH or WMECO. The current portion of Accumulated Deferred Income Taxes as of December 31, 2014, which was included in Total Current Liabilities on the balance sheets, was $160.3 million for Eversource, $34.1 million for CL&P, $55.1 million for NSTAR Electric, $36.2 million for PSNH, and $18.1 million for WMECO.

## D. 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.

## E. Provision for Uncollectible Accounts

Eversource, including CL&P, NSTAR Electric, PSNH and WMECO, 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 WMECO and NSTAR Gas to also recover in rates amounts associated with certain uncollectible hardship accounts receivable. Certain of NSTAR Electric’s uncollectible hardship accounts receivable are expected to be recovered in future rates, similar to WMECO and NSTAR Gas. Uncollectible customer account balances, which are expected to be recovered in rates, are included in Regulatory Assets or Other Long-Term Assets on the balance sheets.

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

<table><tr><td rowspan="2"></td><td colspan="2">Total Provision for Uncollectible Accounts</td><td colspan="2">Uncollectible Hardship</td></tr><tr><td colspan="2">As of December 31,</td><td colspan="2">As of December 31,</td></tr><tr><td>(Millions of Dollars)</td><td>2015</td><td>2014</td><td>2015</td><td>2014</td></tr><tr><td>Eversource</td><td>$ 190.7</td><td>$ 175.3</td><td>$ 118.5</td><td>$ 91.5</td></tr><tr><td>CL&amp;P</td><td>79.5</td><td>84.3</td><td>68.1</td><td>74.0</td></tr><tr><td>NSTAR Electric</td><td>52.6</td><td>40.7</td><td>25.3</td><td>-</td></tr><tr><td>PSNH</td><td>8.7</td><td>7.7</td><td>-</td><td>-</td></tr><tr><td>WMECO</td><td>14.0</td><td>9.9</td><td>7.4</td><td>6.2</td></tr></table>

## F. Fuel, Materials and Supplies and Allowance Inventory

Fuel, Materials and Supplies include natural gas, coal, biomass and oil inventories as well as materials purchased primarily for construction or operation and maintenance purposes. Natural gas, coal, biomass and oil inventories are valued at their respective weighted average cost. Materials and supplies are valued at the lower of average cost or market.

Fuel, Materials and Supplies also include Renewable Energy Certificates (RECs), which are purchased from suppliers of renewable sources of generation. RECs 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 uses  \( SO_{2} \) ,  \( CO_{2} \) , and  \( NO_{x} \)  emissions allowances. At the end of each compliance period, PSNH is required to relinquish  \( SO_{2} \) ,  \( CO_{2} \) , and  \( NO_{x} \)  emissions allowances corresponding to the actual respective emissions emitted by its generating units over the compliance period.  \( SO_{2} \)  and  \( NO_{x} \)  emissions allowances are obtained through an annual allocation from the federal and state regulators that are granted at no cost and through purchases from third parties.  \( CO_{2} \)  emissions allowances are obtained through an annual allocation from the state regulator that are granted at no cost and are acquired through auctions and through purchases from third parties.  \( SO_{2} \) ,  \( CO_{2} \) , and  \( NO_{x} \)  emissions allowances are charged to expense based on their weighted average cost as they are utilized against emissions volumes at PSNH's generating units.  \( SO_{2} \) ,  \( CO_{2} \) , and  \( NO_{x} \)  emissions allowances are recorded within Fuel, Materials and Supplies on the balance sheet and are classified as short-term or long-term depending on the period in which they are expected to be utilized against actual emissions. Current  \( SO_{2} \)  and  \( CO_{2} \)  emissions allowances were classified as Fuel, Materials and Supplies on the balance sheets and long-term  \( SO_{2} \)  and  \( CO_{2} \)  emissions allowances were classified as Other Long-Term Assets on the balance sheets.

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

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="6">As of December 31,</td></tr><tr><td colspan="3">2015</td><td colspan="3">2014</td></tr><tr><td>Eversource</td><td>NSTAR Electric</td><td>PSNH</td><td>Eversource</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>Current:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Fuel</td><td>$ 152.5</td><td>$ -</td><td>$ 103.4</td><td>$ 164.3</td><td>$ -</td><td>$ 95.1</td></tr><tr><td>Materials and Supplies</td><td>131.2</td><td>32.2</td><td>44.6</td><td>159.5</td><td>49.1</td><td>52.2</td></tr><tr><td>RECs</td><td>50.9</td><td>43.3</td><td>7.0</td><td>25.8</td><td>25.1</td><td>0.7</td></tr><tr><td>Emission Allowances</td><td>1.9</td><td>-</td><td>1.9</td><td>0.1</td><td>-</td><td>0.1</td></tr><tr><td>Long-Term:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Emission Allowances</td><td>17.5</td><td>-</td><td>17.5</td><td>20.1</td><td>-</td><td>20.1</td></tr></table>

## G. Deposits

As of December 31, 2015, Eversource, CL&P, NSTAR Electric and PSNH had $17.1 million, $0.7 million, $8.5 million and $1.5 million, respectively, of cash collateral posted not subject to master netting agreements, with ISO-NE related to energy purchase transactions, which was included in Prepayments and Other Current Assets on the balance sheets. As of December 31, 2014, these amounts were $9.9 million, $1.2 million and $2.5 million for Eversource, CL&P and PSNH, respectively.

## H. 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 13, “Fair Value of Financial Instruments” to the financial statements.

## I. Derivative Accounting

Many of the Regulated 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, 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.

## J. Equity Method Investments

Equity investments are included in Other Long-Term Assets on the balance sheets and net earnings related to these equity investments are included in Other Income, Net on the statements of income.

Regional Decommissioned Nuclear Companies: CL&P, NSTAR Electric, PSNH and WMECO 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, PSNH and WMECO, the respective investments in CYPAC, YAEC and MYAPC are accounted for under the equity method. Eversource consolidates CYPAC and YAEC because CL&P’s, NSTAR Electric’s, PSNH’s and WMECO’s combined ownership interest in each of these entities is greater than 50 percent. Intercompany transactions between CL&P, NSTAR Electric, PSNH and WMECO and the CYPAC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.

CL&P’s, NSTAR Electric’s, PSNH’s and WMECO’s ownership interests in the Yankee Companies and the total carrying values, which were included in Other Long-Term Assets on their respective balance sheets, were as follows:

<table><tr><td rowspan="3"></td><td colspan="3">Ownership Interests (percent)</td><td colspan="3">Carrying Amount (in millions)</td></tr><tr><td colspan="3">As of December 31, 2015 and 2014</td><td colspan="3">As of December 31,</td></tr><tr><td>CYAPC</td><td>YAEC</td><td>MYAPC</td><td>2015</td><td>2014</td><td></td></tr><tr><td>CL&amp;P</td><td>34.5 %</td><td>24.5 %</td><td>12.0 %</td><td>$</td><td>1.2</td><td>$ 1.2</td></tr><tr><td>NSTAR Electric</td><td>14.0</td><td>14.0</td><td>4.0</td><td>0.5</td><td>0.5</td><td></td></tr><tr><td>PSNH</td><td>5.0</td><td>7.0</td><td>5.0</td><td>0.3</td><td>0.3</td><td></td></tr><tr><td>WMECO</td><td>9.5</td><td>7.0</td><td>3.0</td><td>0.3</td><td>0.3</td><td></td></tr></table>

For further information on the Yankee Companies, see Note 11C, “Commitments and Contingencies - Contractual Obligations - Yankee Companies,” to the financial statements.



Infrastructure and Other Investments: As of December 31, 2015 and 2014, Eversource had an equity ownership interest in an energy investment fund of $30.3 million and $17.8 million, respectively. Eversource had a 40 percent equity ownership interest in the Algonquin Gas Transmission, LLC (legal entity that owns Access Northeast assets) of $10.7 million as of December 31, 2015.

## K. Revenues

Regulated Companies’ Retail Revenues: The Regulated companies’ retail revenues are based on rates approved by their respective state regulatory commissions. In general, rates can only be changed through formal proceedings with the state regulatory commissions. The Regulated companies’ rates are designed to recover the costs to provide service to their customers, and include a return on investment. The Regulated companies also utilize regulatory commission-approved tracking mechanisms 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.

CL&P (effective December 1, 2014), WMECO, and NSTAR Gas (effective January 1, 2016), each have a regulatory commission approved revenue decoupling mechanism. Distribution revenues are decoupled from customer sales volumes, which breaks the relationship between sales volumes and revenues recognized. CL&P and WMECO 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 incurred during a 12-month period is adjusted through rates in the following period.

A significant portion of the Regulated 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.

Regulated Companies’ 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 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 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.

The Regulated companies estimate unbilled sales monthly using the daily load cycle method. The daily load cycle method allocates billed sales to the current calendar month based on the daily load for each billing cycle. The billed sales are subtracted from total month load, net of delivery losses, to estimate unbilled sales. Unbilled revenues are estimated by first allocating unbilled sales to the respective customer classes, then applying an estimated rate by customer class to those sales. The estimate of unbilled revenues can significantly impact the amount of revenues recorded at NSTAR Electric and PSNH because they do not have a revenue decoupling mechanism. CL&P and WMECO record a regulatory deferral to reflect the actual allowed amount of revenue for decoupling.

Regulated Companies’ Transmission Revenues - Wholesale Rates: Wholesale transmission revenues are recovered through FERC approved formula rates. Wholesale transmission revenues for CL&P, NSTAR Electric, PSNH, and WMECO are collected through a combination of regional and local rates, both of which are under the ISO New England Transmission, Markets and Services Tariff (ISO-NE Tariff). The ISO-NE Tariff includes Regional Network Service (RNS), Schedule 21 – ES rate schedules, which recover the costs of transmission and other transmission-related services for CL&P, PSNH and WMECO, and Schedule 21 - NSTAR rate schedules, which recover costs of transmission and other transmission-related services for NSTAR Electric. The RNS rate, administered by ISO-NE and billed to all New England transmission load, including CL&P, NSTAR Electric, PSNH and WMECO’s distribution businesses, is reset on June 1 \( ^{st} \)  of each year and recovers the revenue requirements associated with Pool Transmission Facilities (PTF) that benefit the entire New England region. The Schedule 21 – ES rate and Schedule 21 - NSTAR rate are administered by Eversource and recover any PTF costs not recovered under RNS rates, as well as the cost of transmission facilities associated with the respective utility’s local system. The Schedule 21 - ES rate is reset on January 1st and June 1st of each year, while the Schedule 21 - NSTAR rate is reset on June 1st of each year. The Schedule 21 – ES rate and Schedule 21 - NSTAR rate calculations recover total transmission revenue requirements net of revenues received from other sources (i.e., RNS, rentals, etc.), thereby ensuring that Eversource recovers all of CL&P’s, NSTAR Electric’s, PSNH’s and WMECO’s regional and local transmission revenue requirements in accordance with the ISO-NE Tariff. The RNS, Schedule 21 – ES rate and Schedule 21 - NSTAR rate 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 refunded to, transmission customers. See Note 11E, “Commitments and Contingencies – FERC ROE Complaints,” for complaints filed at the FERC relating to Eversource’s ROE.

Regulated Companies’ Transmission Revenues - Retail Rates: A significant portion of the Eversource transmission segment revenue comes from ISO-NE charges to the distribution businesses of CL&P, NSTAR Electric, PSNH and WMECO, each of which recovers these costs through rates charged to their retail customers. CL&P, NSTAR Electric, PSNH and WMECO 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.

## L. Operating Expenses

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

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>Eversource - Natural Gas and Fuel</td><td>$     516.7</td><td>$     599.4</td><td>$     466.5</td><td></td></tr><tr><td>PSNH - Fuel</td><td>85.4</td><td>113.4</td><td>104.8</td><td></td></tr></table>



## M. 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 Regulated companies' utility plant on the balance sheet. The portion of AFUDC attributable to borrowed funds is recorded as a reduction of Other 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 Regulated companies’ 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="6">For the Years Ended December 31,</td></tr><tr><td colspan="2">2015</td><td colspan="2">2014</td><td colspan="2">2013</td></tr><tr><td>Borrowed Funds</td><td>$ 7.2</td><td>$ 7.2</td><td>5.8</td><td>$ 4.1</td><td></td><td></td></tr><tr><td>Equity Funds</td><td>18.8</td><td></td><td>13.7</td><td></td><td>7.1</td><td></td></tr><tr><td>Total AFUDC</td><td>$ 26.0</td><td>$ 26.0</td><td>19.5</td><td>$ 11.2</td><td></td><td></td></tr><tr><td>Average AFUDC Rate</td><td>3.9%</td><td></td><td>3.4%</td><td></td><td>2.7%</td><td></td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars, except percentages)</td><td colspan="4">2015</td><td colspan="4">2014</td><td colspan="4">2013</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>Cl&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td></tr><tr><td>Borrowed Funds</td><td>$ 2.6</td><td>$ 2.0</td><td>$ 1.0</td><td>$ 1.0</td><td>$ 1.9</td><td>$ 2.0</td><td>$ 0.6</td><td>$ 0.9</td><td>$ 2.2</td><td>$ 0.5</td><td>$ 0.5</td><td>$ 0.5</td></tr><tr><td>Equity Funds</td><td>5.2</td><td>4.3</td><td>1.2</td><td>1.7</td><td>2.9</td><td>3.8</td><td>0.6</td><td>1.7</td><td>2.9</td><td>-</td><td>0.2</td><td>1.0</td></tr><tr><td>Total AFUDC</td><td>$ 7.8</td><td>$ 6.3</td><td>$ 2.2</td><td>$ 2.7</td><td>$ 4.8</td><td>$ 5.8</td><td>$ 1.2</td><td>$ 2.6</td><td>$ 5.1</td><td>$ 0.5</td><td>$ 0.7</td><td>$ 1.5</td></tr><tr><td>Average AFUDC Rate</td><td>5.5%</td><td>3.2%</td><td>1.8%</td><td>4.4%</td><td>3.4%</td><td>2.5%</td><td>1.8%</td><td>5.6%</td><td>3.7%</td><td>0.5%</td><td>1.1%</td><td>6.1%</td></tr></table>

## N. Other Income, Net

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

## O. Other Taxes

Gross receipts taxes levied by the state of Connecticut are collected by CL&P and Yankee Gas from their respective 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="3">For the Years Ended December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td></tr><tr><td>Eversource</td><td>$ 147.2</td><td>$ 148.2</td><td>$ 144.1</td></tr><tr><td>CL&amp;P</td><td>128.5</td><td>127.9</td><td>128.2</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.

## P. 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>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>Cash Paid During the Year for:</td><td></td><td></td><td></td><td></td></tr><tr><td>Interest, Net of Amounts Capitalized</td><td>$ 365.9</td><td>$ 349.6</td><td>$ 343.3</td><td></td></tr><tr><td>Income Taxes</td><td>10.3</td><td>334.2</td><td>50.0</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>216.6</td><td>181.9</td><td>193.1</td><td></td></tr></table>

As of and For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">2015</td><td colspan="4">2014</td><td colspan="4">2013</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>Cl&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</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><td></td><td></td><td></td></tr><tr><td>Interest, Net of Amounts Capitalized</td><td>$ 144.4</td><td>$ 75.7</td><td>$ 42.3</td><td>$ 26.7</td><td>$ 144.1</td><td>$ 75.3</td><td>$ 41.1</td><td>$ 25.9</td><td>$ 131.6</td><td>$ 75.8</td><td>$ 43.3</td><td>$ 25.8</td></tr><tr><td>Income Taxes</td><td>55.2</td><td>(19.8)</td><td>14.4</td><td>14.7</td><td>135.4</td><td>217.1</td><td>2.3</td><td>25.1</td><td>55.0</td><td>163.4</td><td>(30.1)</td><td>(69.0)</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><td></td><td></td><td></td></tr><tr><td>Plant Additions Included in Accounts Payable (As of)</td><td>76.0</td><td>23.5</td><td>46.5</td><td>27.0</td><td>63.5</td><td>34.6</td><td>39.3</td><td>14.2</td><td>51.4</td><td>57.0</td><td>34.9</td><td>19.5</td></tr></table>



The 2015 cash paid for interest excludes interest payments made by CL&P and WMECO 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 further information, see Note 8, “Long-Term Debt,” to the financial statements.

In 2014, 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 - Contractual Obligations - Yankee Companies,” Eversource received total proceeds of $132.1 million, which were net of $80.6 million in proceeds CYAPC and YAEC returned to non-affiliated member companies.

## Q. 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, 2015 and 2014, CL&P, PSNH and WMECO had long-term receivables from Eversource Service in the amounts of $25 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, PSNH and WMECO employees and have been eliminated in consolidation on the Eversource financial statements.

Included in the CL&P, NSTAR Electric, PSNH and WMECO balance sheets as of December 31, 2015 and 2014 were Accounts Receivable from Affiliated Companies and Accounts Payable to Affiliated Companies relating to transactions between CL&P, NSTAR Electric, PSNH and WMECO and other subsidiaries that are wholly-owned by Eversource. These amounts have been eliminated in consolidation on the Eversource financial statements.

## R. Severance Benefits

For the years ended December 31, 2015, 2014 and 2013, Eversource recorded severance benefit expense of $4.7 million, $15 million and $9.7 million, respectively, in connection with organizational and cost saving initiatives, and, in 2014, the partial outsourcing of information technology functions. As of December 31, 2015 and 2014, the severance accrual totaled $9.3 million and $10.4 million, respectively, and was included in Other Current Liabilities on the balance sheets.

## 2. REGULATORY ACCOUNTING

Eversource’s Regulated companies are subject to rate-regulation that is based on cost recovery and meets the criteria for application of accounting guidance for rate-regulated operations, which considers the effect of regulation on the timing of the recognition of certain revenues and expenses. The Regulated companies’ financial statements reflect the effects of the rate-making process. The rates charged to the customers of 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 their 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>2015</td><td>2014</td></tr><tr><td>Benefit Costs</td><td>$ 1,828.2</td><td>$ 2,016.0</td></tr><tr><td>Derivative Liabilities</td><td>388.0</td><td>425.5</td></tr><tr><td>Income Taxes, Net</td><td>650.9</td><td>635.3</td></tr><tr><td>Storm Restoration Costs</td><td>436.9</td><td>502.8</td></tr><tr><td>Goodwill-related</td><td>484.9</td><td>505.4</td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>526.5</td><td>350.5</td></tr><tr><td>Contractual Obligations - Yankee Companies</td><td>134.4</td><td>123.8</td></tr><tr><td>Other Regulatory Assets</td><td>134.0</td><td>167.3</td></tr><tr><td>Total Regulatory Assets</td><td>4,583.8</td><td>4,726.6</td></tr><tr><td>Less: Current Portion</td><td>845.8</td><td>672.5</td></tr><tr><td>Total Long-Term Regulatory Assets</td><td>$ 3,738.0</td><td>$ 4,054.1</td></tr></table>



As of December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">2015</td><td colspan="5">2014</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td></td><td></td></tr><tr><td>Benefit Costs</td><td>$ 413.6</td><td>$ 479.9</td><td>$ 164.2</td><td>$ 84.9</td><td>$ 445.4</td><td>$ 515.9</td><td>$ 174.3</td><td>$ 85.0</td><td></td><td></td></tr><tr><td>Derivative Liabilities</td><td>380.8</td><td>1.3</td><td>-</td><td>-</td><td>410.9</td><td>4.5</td><td>-</td><td>-</td><td></td><td></td></tr><tr><td>Income Taxes, Net</td><td>444.4</td><td>85.7</td><td>34.5</td><td>31.8</td><td>437.7</td><td>83.7</td><td>38.0</td><td>35.5</td><td></td><td></td></tr><tr><td>Storm Restoration Costs</td><td>271.4</td><td>110.9</td><td>31.5</td><td>23.1</td><td>319.6</td><td>103.7</td><td>47.7</td><td>31.8</td><td></td><td></td></tr><tr><td>Goodwill-related</td><td>-</td><td>416.3</td><td>-</td><td>-</td><td>-</td><td>433.9</td><td>-</td><td>-</td><td></td><td></td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>45.1</td><td>311.0</td><td>101.2</td><td>40.1</td><td>16.1</td><td>141.4</td><td>103.5</td><td>33.0</td><td></td><td></td></tr><tr><td>Other Regulatory Assets</td><td>82.0</td><td>56.3</td><td>31.5</td><td>11.3</td><td>66.1</td><td>94.7</td><td>41.3</td><td>12.9</td><td></td><td></td></tr><tr><td>Total Regulatory Assets</td><td>1,637.3</td><td>1,461.4</td><td>362.9</td><td>191.2</td><td>1,695.8</td><td>1,377.8</td><td>404.8</td><td>198.2</td><td></td><td></td></tr><tr><td>Less: Current Portion</td><td>268.3</td><td>348.4</td><td>105.0</td><td>56.2</td><td>220.3</td><td>198.7</td><td>111.7</td><td>51.9</td><td></td><td></td></tr><tr><td>Total Long-Term Regulatory Assets</td><td>$ 1,369.0</td><td>$ 1,113.0</td><td>$ 257.9</td><td>$ 135.0</td><td>$ 1,475.5</td><td>$ 1,179.1</td><td>$ 293.1</td><td>$ 146.3</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 recorded by the Regulated companies to recognize the funded status of their retiree benefit plans is offset by a regulatory asset in lieu of a charge to Accumulated Other Comprehensive Income/(Loss), reflecting ultimate recovery from customers through rates. The regulatory asset 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 do not represent a cash outlay for the Regulated companies, no carrying charge is recovered from customers.

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

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, PSNH and WMECO 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. Of the total deferred storm restoration costs, $197 million is pending regulatory approval (including $106 million at NSTAR Electric, $61 million at PSNH, and $30 million at WMECO). 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 earns a return on its deferred storm restoration cost regulatory asset balance.

Goodwill-related: The goodwill regulatory asset originated from a 1999 merger 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, 2015, there were 24 years of amortization remaining.

Regulatory Tracker Mechanisms: The Regulated companies’ approved rates are designed to recover their 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 recorded on all material regulatory tracker mechanisms.

CL&P, NSTAR Electric, PSNH and WMECO 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 (including LBR at NSTAR Electric), 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 generating stations and at WMECO include the costs related to its solar generation.



CL&P (effective December 1, 2014) and WMECO each have a regulatory commission approved revenue decoupling mechanism. Distribution revenues are decoupled from customer sales volumes, which breaks the relationship between sales volumes and revenues recognized. CL&P and WMECO 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 received during a 12-month period is adjusted through rates in the following period. CL&P and WMECO’s revenue decoupling mechanisms permit recovery of an annual base amount of distribution revenues of $1.059 billion and $132.4 million, respectively.

Contractual Obligations - Yankee Companies: CL&P, NSTAR Electric, PSNH and WMECO are responsible for their proportionate share of the remaining costs of the CYAPC, YAEC and MYAPC nuclear facilities, including nuclear fuel storage. A portion of these costs was recorded as a regulatory asset. Amounts for CL&P are earning a return and are being recovered through the CTA. Amounts for NSTAR Electric and WMECO are being recovered without a return through the transition charge. Amounts for PSNH were fully recovered in 2006. As a result of Eversource’s consolidation of CYAPC and YAEC, Eversource’s regulatory asset balance also includes the regulatory assets of CYAPC and YAEC, which totaled $110.9 million and $97.8 million as of December 31, 2015 and 2014, respectively. Intercompany transactions between CL&P, NSTAR Electric, PSNH and WMECO and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.

Other Regulatory Assets: Other Regulatory Assets primarily include asset retirement obligations, environmental remediation costs, losses associated with the reacquisition or redemption of long-term debt, purchase power contract termination costs and various other items.

Regulatory Costs in Other Long-Term Assets: The Regulated companies had $75.3 million (including $3.1 million for CL&P, $35.4 million for NSTAR Electric, $4.8 million for PSNH and $16.7 million for WMECO) and $60.5 million (including $1.3 million for CL&P, $33.2 million for NSTAR Electric, $0.9 million for PSNH, and $11 million for WMECO) of additional regulatory costs as of December 31, 2015 and 2014, respectively, that were included in Other 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. The NSTAR Electric balance as of December 31, 2015 and 2014 primarily related to the deferral of certain bad debt costs expected to be recovered in future 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 $1.5 million and $1.7 million for CL&P as of December 31, 2015 and 2014, respectively. These carrying costs will be recovered from customers in future rates.

As of December 31, 2015 and 2014, this equity return, which is not recorded on the balance sheets, totaled $48.3 million and $43.3 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 pending NHPUC approval of a generation divestiture settlement agreement. For further information on the divestiture, see Note 11H, “Commitments and Contingencies – PSNH Generation Restructuring.”

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

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="4">As of December 31,</td></tr><tr><td>2015</td><td>2014</td><td></td><td></td></tr><tr><td>Cost of Removal</td><td>$ 437.1</td><td>$ 439.9</td><td></td><td></td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>99.7</td><td>192.3</td><td></td><td></td></tr><tr><td>AFUDC - Transmission</td><td>66.1</td><td>67.1</td><td></td><td></td></tr><tr><td>Other Regulatory Liabilities</td><td>18.5</td><td>50.8</td><td></td><td></td></tr><tr><td>Total Regulatory Liabilities</td><td>621.4</td><td>750.1</td><td></td><td></td></tr><tr><td>Less: Current Portion</td><td>107.8</td><td>235.0</td><td></td><td></td></tr><tr><td>Total Long-Term Regulatory Liabilities</td><td>$ 513.6</td><td>$ 515.1</td><td></td><td></td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="4">2015</td><td colspan="4">2014</td></tr><tr><td colspan="2">NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td colspan="2">CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td></tr><tr><td>(Millions of Dollars)</td><td>CL&amp;P</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td></td></tr><tr><td>Cost of Removal</td><td>$ 24.1</td><td>$ 257.4</td><td>$ 47.2</td><td>$ 2.8</td><td>$ 19.7</td><td>$ 258.3</td><td>$ 50.3</td><td>$ 1.1</td></tr><tr><td>Regulatory Tracker Mechanisms</td><td>56.2</td><td>3.3</td><td>3.4</td><td>12.9</td><td>122.6</td><td>20.7</td><td>14.2</td><td>22.3</td></tr><tr><td>AFUDC - Transmission</td><td>51.5</td><td>5.7</td><td>-</td><td>8.9</td><td>53.6</td><td>4.4</td><td>-</td><td>9.1</td></tr><tr><td>Other Regulatory Liabilities</td><td>4.2</td><td>1.3</td><td>4.2</td><td>0.1</td><td>10.1</td><td>28.9</td><td>2.9</td><td>0.8</td></tr><tr><td>Total Regulatory Liabilities</td><td>136.0</td><td>267.7</td><td>54.8</td><td>24.7</td><td>206.0</td><td>312.3</td><td>67.4</td><td>33.3</td></tr><tr><td>Less: Current Portion</td><td>61.2</td><td>3.3</td><td>6.9</td><td>13.1</td><td>124.7</td><td>49.6</td><td>16.0</td><td>22.5</td></tr><tr><td>Total Long-Term Regulatory Liabilities</td><td>$ 74.8</td><td>$ 264.4</td><td>$ 47.9</td><td>$ 11.6</td><td>$ 81.3</td><td>$ 262.7</td><td>$ 51.4</td><td>$ 10.8</td></tr></table>

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. Expended costs that exceed amounts collected from customers are recognized as regulatory assets, as they are probable of recovery in future rates.

AFUDC - Transmission: Regulatory liabilities were recorded by CL&P and WMECO for AFUDC accrued on certain reliability-related transmission projects to reflect local rate base recovery as a result of a FERC-approved transmission tariff. A regulatory liability was recorded by NSTAR Electric for AFUDC accrued on certain reliability-related transmission projects through December 31, 2015 to reflect local rate base recovery. These regulatory liabilities for CL&P, NSTAR Electric and WMECO will be amortized over the depreciable life of the related transmission assets.



## 2015 Regulatory Developments:

FERC ROE Complaints: As a result of the actions taken by the FERC and other developments in the pending ROE complaint proceedings described in Note 11E, “Commitments and Contingencies – FERC ROE Complaints,” Eversource recorded reserves for the first and second ROE complaints, which were recorded as a regulatory liability and as a reduction to operating revenues. The cumulative pre-tax reserves (excluding interest) as of December 31, 2015, which include the impact of refunds given to customers, totaled $39.1 million for Eversource (including $21.4 million for CL&P, $8.5 million for NSTAR Electric, $3.1 million for PSNH, and $6.1 million for WMECO).

NSTAR Electric and NSTAR Gas Comprehensive Settlement Agreement: On March 2, 2015, the DPU approved the comprehensive settlement agreement between NSTAR Electric, NSTAR Gas and the Massachusetts Attorney General (the "Settlement") as filed with the DPU on December 31, 2014. The Settlement resolved the outstanding NSTAR Electric CPSL program filings for 2006 through 2011, the NSTAR Electric and NSTAR Gas PAM and energy efficiency-related customer billing adjustments reported in 2012, and the recovery of LBR related to NSTAR Electric's energy efficiency programs for 2009 through 2011 (11 dockets in total). In 2015, as a result of the DPU order, NSTAR Electric and NSTAR Gas commenced refunding a combined $44.7 million to customers, which was recorded as a regulatory liability. Refunds to customers will continue through December 2016. As a result of the Settlement, NSTAR Electric increased its operating revenues and decreased its amortization expense in 2015, resulting in the recognition of a $21.7 million pre-tax benefit in 2015.

NSTAR Electric Basic Service Bad Debt Adder: On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006. As a result of the DPU order, in the first quarter of 2015, NSTAR Electric increased its regulatory assets and reduced its operations and maintenance expense by an under recovered amount of $24.2 million for energy-related bad debt costs through 2014, resulting in a pre-tax benefit in 2015. NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers and on November 20, 2015 the DPU approved NSTAR Electric's proposed rate increase to recover these costs over a 12-month period, effective January 1, 2016.

CL&P Distribution Rates: On July 2, 2015, PURA issued a final order that approved a settlement agreement filed on May 19, 2015, which allows for an increase to rate base of approximately $163 million associated with ADIT, including a regulatory asset to recover the incremental revenue requirement for the period December 1, 2014 through November 30, 2015 over a subsequent 24-month period. The rate base increase provided an increase to total allowed annual revenue requirements of $18.4 million beginning December 1, 2014. As part of the settlement agreement, the $18.4 million for the period December 1, 2014 through November 30, 2015 was recorded as a regulatory asset with a corresponding increase in Operating Revenues, and is being collected from customers in rates over a 24-month period beginning December 1, 2015.

NSTAR Gas Distribution Rates: On October 30, 2015, the DPU issued its order in the NSTAR Gas distribution rate case, which approved 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 GSA, 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. On November 19, 2015, NSTAR Gas filed a motion for reconsideration of the order with the DPU seeking the correction of mathematical errors and other plant and cost of service items.

As a result of this order, Eversource recorded regulatory deferrals for costs that have been approved for recovery or are expected to be approved for recovery in future rate proceedings, which resulted in the recognition of a $17.2 million pre-tax benefit in 2015. Included in this amount is a $10.5 million pre-tax benefit recorded at NSTAR Electric for certain uncollectible hardship accounts receivable that are expected to be recovered in future rates given the allowed recoveries of uncollectible hardship accounts receivable by WMECO and NSTAR Gas.

## 3. PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

Utility property, plant and equipment is recorded at original cost. Original cost includes materials, labor, construction overhead and AFUDC for regulated property. The cost of repairs and maintenance, including planned major maintenance activities, is charged to Operating Expenses as incurred.

The following tables summarize the investments in utility 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>2015</td><td>2014</td></tr><tr><td>Distribution - Electric</td><td>$ 13,054.8</td><td>$ 12,495.2</td></tr><tr><td>Distribution - Natural Gas</td><td>2,727.2</td><td>2,595.4</td></tr><tr><td>Transmission - Electric</td><td>7,691.9</td><td>6,930.7</td></tr><tr><td>Generation</td><td>1,194.1</td><td>1,170.9</td></tr><tr><td>Electric and Natural Gas Utility</td><td>24,668.0</td><td>23,192.2</td></tr><tr><td>Other \( ^{(1)} \)</td><td>558.6</td><td>551.3</td></tr><tr><td>Property, Plant and Equipment, Gross</td><td>25,226.6</td><td>23,743.5</td></tr><tr><td>Less: Accumulated Depreciation</td><td></td><td></td></tr><tr><td>Electric and Natural Gas Utility</td><td>(6,141.1)</td><td>(5,777.8)</td></tr><tr><td>Other</td><td>(255.6)</td><td>(231.8)</td></tr><tr><td>Total Accumulated Depreciation</td><td>(6,396.7)</td><td>(6,009.6)</td></tr><tr><td>Property, Plant and Equipment, Net</td><td>18,829.9</td><td>17,733.9</td></tr><tr><td>Construction Work in Progress</td><td>1,062.5</td><td>913.1</td></tr><tr><td>Total Property, Plant and Equipment, Net</td><td>$ 19,892.4</td><td>$ 18,647.0</td></tr></table>

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



As of December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">2015</td><td colspan="5">2014</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td></td><td></td></tr><tr><td>Distribution</td><td>$ 5,377.2</td><td>$ 5,100.5</td><td>$ 1,804.8</td><td>$ 812.3</td><td>$ 5,158.8</td><td>$ 4,895.5</td><td>$ 1,696.7</td><td>$ 784.2</td><td></td><td></td></tr><tr><td>Transmission</td><td>3,618.0</td><td>2,131.3</td><td>928.2</td><td>964.9</td><td>3,274.0</td><td>1,928.5</td><td>789.7</td><td>891.0</td><td></td><td></td></tr><tr><td>Generation</td><td>-</td><td>-</td><td>1,158.1</td><td>36.0</td><td>-</td><td>-</td><td>1,136.5</td><td>34.4</td><td></td><td></td></tr><tr><td>Property, Plant and Equipment, Gross</td><td>8,995.2</td><td>7,231.8</td><td>3,891.1</td><td>1,813.2</td><td>8,432.8</td><td>6,824.0</td><td>3,622.9</td><td>1,709.6</td><td></td><td></td></tr><tr><td>Less: Accumulated Depreciation</td><td>(2,041.9)</td><td>(1,886.8)</td><td>(1,171.0)</td><td>(307.0)</td><td>(1,928.0)</td><td>(1,761.4)</td><td>(1,090.0)</td><td>(297.4)</td><td></td><td></td></tr><tr><td>Property, Plant and Equipment, Net</td><td>6,953.3</td><td>5,345.0</td><td>2,720.1</td><td>1,506.2</td><td>6,504.8</td><td>5,062.6</td><td>2,532.9</td><td>1,412.2</td><td></td><td></td></tr><tr><td>Construction Work in Progress</td><td>203.5</td><td>310.5</td><td>135.3</td><td>69.1</td><td>304.9</td><td>272.8</td><td>102.9</td><td>49.1</td><td></td><td></td></tr><tr><td>Total Property, Plant and Equipment, Net</td><td>$ 7,156.8</td><td>$ 5,655.5</td><td>$ 2,855.4</td><td>$ 1,575.3</td><td>$ 6,809.7</td><td>$ 5,335.4</td><td>$ 2,635.8</td><td>$ 1,461.3</td><td></td><td></td></tr></table>

As of December 31, 2015, PSNH had $1.2 billion in gross generation utility plant assets and related Accumulated Depreciation of $522.4 million. These generation assets are the subject of a divestiture agreement entered into on June 10, 2015 between Eversource, PSNH and key New Hampshire officials whereby, among other resolutions, PSNH has agreed to divest these generation assets upon NHPUC approval. Upon completion of the divestiture process, remaining costs not recovered by the sale of these assets (stranded costs) will be recovered via bonds that will be secured by a non-bypassable charge or other recovery mechanisms in rates billed to PSNH’s customers. See Note 11H, “Commitments and Contingencies – PSNH Generation Restructuring,” for further information.

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). The composite rates, which are subject to approval by the appropriate state regulatory agency, include a cost of removal component (other than PSNH Generation), 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>2015</td><td>2014</td><td>2013</td></tr><tr><td>Eversource</td><td>2.9%</td><td>3.0%</td><td>2.8%</td></tr><tr><td>CL&amp;P</td><td>2.7%</td><td>2.7%</td><td>2.5%</td></tr><tr><td>NSTAR Electric</td><td>3.0%</td><td>3.0%</td><td>2.9%</td></tr><tr><td>PSNH</td><td>3.2%</td><td>3.0%</td><td>3.0%</td></tr><tr><td>WMECO</td><td>2.7%</td><td>3.3%</td><td>2.9%</td></tr></table>

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

<table><tr><td rowspan="2">(Years)</td><td colspan="5">As of December 31, 2015</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td></tr><tr><td>Distribution</td><td>34.8</td><td>37.3</td><td>31.9</td><td>31.3</td><td>30.5</td></tr><tr><td>Transmission</td><td>41.6</td><td>38.7</td><td>43.8</td><td>41.6</td><td>50.0</td></tr><tr><td>Generation</td><td>30.7</td><td>-</td><td>-</td><td>30.9</td><td>25.0</td></tr><tr><td>Other</td><td>14.1</td><td>-</td><td>-</td><td>-</td><td>-</td></tr></table>

## 4. DERIVATIVE INSTRUMENTS

The Regulated 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. The Regulated companies manage the risks associated with the price volatility of energy and energy-related products through the use of derivative and nonderivative 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 Regulated 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="2"></td><td colspan="8">As of December 31,</td></tr><tr><td colspan="3">2015</td><td colspan="3">2014</td><td colspan="2">Net Amount Recorded as a Derivative</td></tr><tr><td>(Millions of Dollars)</td><td>Commodity Supply and Price Risk Management</td><td>Netting (1)</td><td>Net Amount Recorded as a Derivative</td><td>Commodity Supply and Price Risk Management</td><td>Netting (1)</td><td></td><td></td><td></td></tr><tr><td>Current Derivative Assets:</td><td></td><td></td><td></td><td></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><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, 2015, Eversource’s and CL&P’s derivative assets were exposed to counterparty credit risk. Of Eversource’s and CL&P’s derivative assets, approximately $47 million was contracted with investment grade entities.

For further information on the fair value of derivative contracts, see Note 1H, “Summary of Significant Accounting Policies - Fair Value Measurements,” and Note 1I, “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 or to 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.

NSTAR Electric has a renewable energy contract to purchase 0.1 million MWh of energy per year through 2018 and a capacity-related contract to purchase up to 35 MW per year through 2019.

As of December 31, 2015 and 2014, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately 9.1 million and 8.8 million MMBtu of natural gas, respectively.

For the years ended December 31, 2015, 2014 and 2013, there were losses of $60.2 million and gains of $134.4 million and $160.6 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, 2015 and 2014, Eversource had $5.8 million and $10 million, respectively, 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 $5.8 million and $10 million, respectively, if Eversource parent’s unsecured debt credit ratings had been downgraded to below investment grade.

## 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 relating 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 time period 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 Eversource’s, including CL&P’s and NSTAR Electric’s, Level 3 derivative contracts and the range of the significant unobservable inputs utilized in their respective valuations over the duration of the contracts:

<table><tr><td rowspan="2"></td><td colspan="6">As of December 31,</td></tr><tr><td colspan="3">2015</td><td colspan="3">2014</td></tr><tr><td></td><td colspan="2">Range</td><td>Period Covered</td><td colspan="2">Range</td><td>Period Covered</td></tr><tr><td>Capacity Prices:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource</td><td>$ 10.81 - 15.82</td><td>per kW-Month</td><td>2016 - 2026</td><td>$ 5.30 - 12.98</td><td>per kW-Month</td><td>2016 - 2026</td></tr><tr><td>CL&amp;P</td><td>$ 10.81 - 12.60</td><td>per kW-Month</td><td>2019 - 2026</td><td>$ 11.08 - 12.98</td><td>per kW-Month</td><td>2018 - 2026</td></tr><tr><td>NSTAR Electric</td><td>$ 10.81 - 15.82</td><td>per kW-Month</td><td>2016 - 2019</td><td>$ 5.30 - 11.10</td><td>per kW-Month</td><td>2016 - 2019</td></tr><tr><td>Forward Reserve:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource, CL&amp;P</td><td>$ 2.00</td><td>per kW-Month</td><td>2016 - 2024</td><td>$ 5.80 - 9.50</td><td>per kW-Month</td><td>2015 - 2024</td></tr><tr><td>REC Prices:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Eversource, NSTAR Electric</td><td>$ 45 - 51</td><td>per REC</td><td>2016 - 2018</td><td>$ 38 - 56</td><td>per REC</td><td>2015 - 2018</td></tr></table>

Exit price premiums of 5 percent to 22 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><td>NSTAR Electric</td></tr><tr><td>Derivatives, Net:</td><td></td><td></td><td></td></tr><tr><td>Fair Value as of January 1, 2014</td><td>$ (635.2)</td><td>$ (630.6)</td><td>$ (7.3)</td></tr><tr><td>Net Realized/Unrealized Gains Included in Regulatory Assets and Liabilities</td><td>141.3</td><td>139.7</td><td>4.3</td></tr><tr><td>Settlements</td><td>78.5</td><td>80.0</td><td>(1.5)</td></tr><tr><td>Fair Value as of December 31, 2014</td><td>$ (415.4)</td><td>$ (410.9)</td><td>$ (4.5)</td></tr><tr><td>Net Realized/Unrealized Losses Included in Regulatory Assets and Liabilities</td><td>(52.1)</td><td>(51.3)</td><td>(0.8)</td></tr><tr><td>Settlements</td><td>86.6</td><td>81.4</td><td>5.2</td></tr><tr><td>Fair Value as of December 31, 2015</td><td>$ (380.9)</td><td>$ (380.8)</td><td>$ (0.1)</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 decommissioning and spent nuclear fuel removal obligations of their nuclear fuel storage facilities.

WMECO maintained a spent nuclear fuel trust to fund WMECO’s pre-1983 spent nuclear fuel obligation. In late 2015, this trust was liquidated to satisfy the spent nuclear fuel obligation with the DOE. For further information, see Note 8, “Long-Term Debt.”



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, 2015 and 2014, these securities were classified as Level 1 in the fair value hierarchy and totaled $14.2 million and $85.1 million, respectively. For the years ended December 31, 2015, 2014 and 2013, net gains on these securities of $2 million, $1.9 million and $10.2 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. In 2015, certain of the securities classified as trading securities were sold and the proceeds were re-invested in equity securities designated as available-for-sale securities.

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"></td><td colspan="12">2015</td></tr><tr><td colspan="3">Amortized Cost</td><td colspan="3">Pre-Tax Unrealized Gains</td><td colspan="3">Pre-Tax Unrealized Losses</td><td colspan="3">Fair Value</td><td colspan="2">2014</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><td></td></tr><tr><td>Eversource</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><td></td></tr><tr><td>Debt Securities (1) (2)</td><td>$ 256.5</td><td>$ 4.5</td><td>$ (0.6)</td><td>$ 260.4</td><td>$ 313.0</td><td>$ 7.5</td><td>$ (0.3)</td><td>$ 320.2</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Equity Securities (1)</td><td>215.3</td><td>59.2</td><td>(3.4)</td><td>271.1</td><td>160.6</td><td>73.3</td><td>-</td><td>233.9</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>WMECO</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><td></td></tr><tr><td>Debt Securities (2)</td><td>-</td><td>-</td><td>-</td><td>-</td><td>58.2</td><td>-</td><td>(0.1)</td><td>58.1</td><td></td><td></td><td></td><td></td><td></td></tr></table>

(1) Amounts include CYAPC’s and YAEC’s marketable securities held in nuclear decommissioning trusts of $436.9 million and $450.8 million as of December 31, 2015 and 2014, respectively. Unrealized gains and losses for the 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.

(2) Unrealized gains and losses on debt securities held by WMECO were recorded in Marketable Securities with the corresponding offset to Other Long-Term Assets on the balance sheets.

Unrealized Losses and Other-than-Temporary Impairment: There have been no significant unrealized losses, other-than-temporary impairments or credit losses in 2015 or 2014. 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.

Contractual Maturities: As of December 31, 2015, 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>$ 33.3</td><td>$ 33.2</td></tr><tr><td>One to five years</td><td>50.2</td><td>50.7</td></tr><tr><td>Six to ten years</td><td>56.6</td><td>57.2</td></tr><tr><td>Greater than ten years</td><td>116.4</td><td>119.3</td></tr><tr><td>Total Debt Securities</td><td>$ 256.5</td><td>$ 260.4</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="2">As of December 31,</td></tr><tr><td>2015</td><td>2014</td></tr><tr><td>Level 1:</td><td></td><td></td></tr><tr><td>Mutual Funds and Equities</td><td>$ 285.3</td><td>$ 319.0</td></tr><tr><td>Money Market Funds</td><td>26.9</td><td>24.9</td></tr><tr><td>Total Level 1</td><td>$ 312.2</td><td>$ 343.9</td></tr><tr><td>Level 2:</td><td></td><td></td></tr><tr><td>U.S. Government Issued Debt Securities (Agency and Treasury)</td><td>$ 46.6</td><td>$ 51.3</td></tr><tr><td>Corporate Debt Securities</td><td>43.9</td><td>49.1</td></tr><tr><td>Asset-Backed Debt Securities</td><td>20.0</td><td>54.1</td></tr><tr><td>Municipal Bonds</td><td>111.4</td><td>116.3</td></tr><tr><td>Other Fixed Income Securities</td><td>11.6</td><td>24.5</td></tr><tr><td>Total Level 2</td><td>$ 233.5</td><td>$ 295.3</td></tr><tr><td>Total Marketable Securities</td><td>$ 545.7</td><td>$ 639.2</td></tr></table>



As of December 31, 2014, the WMECO spent nuclear fuel trust included investments in money market funds of $4.3 million classified as Level 1 in the fair value hierarchy, and $14.7 million of corporate debt securities, $14.5 million of asset-backed debt securities, $13 million of municipal bonds and $11.6 million of other fixed income securities classified as Level 2 in the fair value hierarchy. The trust was liquidated in late 2015.

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 instrument 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, PSNH and WMECO, recognizes a liability for the fair value of an ARO on the obligation date if the liability’s fair value can be reasonably estimated and 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 with corresponding credits recorded as accumulated depreciation and ARO liabilities, respectively. As the Regulated 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 the Regulated 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="2">As of December 31,</td></tr><tr><td>2015</td><td>2014</td></tr><tr><td>Balance as of Beginning of Year</td><td>$ 426.3</td><td>$ 424.9</td></tr><tr><td>Liabilities Incurred During the Year</td><td>6.6</td><td>1.3</td></tr><tr><td>Liabilities Settled During the Year</td><td>(18.2)</td><td>(19.5)</td></tr><tr><td>Accretion</td><td>26.5</td><td>25.1</td></tr><tr><td>Revisions in Estimated Cash Flows</td><td>(11.1)</td><td>(5.5)</td></tr><tr><td>Balance as of End of Year</td><td>$ 430.1</td><td>$ 426.3</td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="5">2015</td><td colspan="5">2014</td></tr><tr><td colspan="2">NSTAR Electric</td><td colspan="2">PSNH</td><td colspan="2">WMECO</td><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td></tr><tr><td>(Millions of Dollars)</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</td><td></td><td></td></tr><tr><td>Balance as of Beginning of Year</td><td>$ 35.3</td><td>$ 34.3</td><td>$ 20.6</td><td>$ 5.9</td><td>$ 35.0</td><td>$ 32.8</td><td>$ 19.5</td><td>$ 4.5</td><td></td><td></td></tr><tr><td>Liabilities Incurred During the Year</td><td>-</td><td>6.2</td><td>0.4</td><td>-</td><td>-</td><td>-</td><td>-</td><td>-</td><td>1.1</td><td></td></tr><tr><td>Liabilities Settled During the Year</td><td>-</td><td>(1.5)</td><td>-</td><td>(0.1)</td><td>(1.1)</td><td>-</td><td>-</td><td>-</td><td>-</td><td></td></tr><tr><td>Accretion</td><td>2.2</td><td>1.8</td><td>1.3</td><td>0.4</td><td>1.9</td><td>1.5</td><td>1.1</td><td>0.3</td><td></td><td></td></tr><tr><td>Revisions in Estimated Cash Flows</td><td>(3.7)</td><td>(5.5)</td><td>(0.7)</td><td>(0.5)</td><td>(0.5)</td><td>-</td><td>-</td><td>-</td><td>-</td><td></td></tr><tr><td>Balance as of End of Year</td><td>$ 33.8</td><td>$ 35.3</td><td>$ 21.6</td><td>$ 5.7</td><td>$ 35.3</td><td>$ 34.3</td><td>$ 20.6</td><td>$ 5.9</td><td></td><td></td></tr></table>

Eversource’s amounts include CYAPC and YAEC’s AROs of $319.1 million and $317.3 million as of December 31, 2015 and 2014, 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 Borrowing Limits: The amount of short-term borrowings that may be incurred by CL&P, NSTAR Electric and WMECO is subject to periodic approval by the FERC. As a result of the NHPUC having jurisdiction over PSNH’s short-term debt, PSNH is not currently required to obtain FERC approval for its short-term borrowings. On June 16, 2015, the FERC granted authorization that allows CL&P and WMECO to incur total short-term borrowings up to a maximum of $600 million and $300 million, respectively, effective January 1, 2016 through December 31, 2017. On June 11, 2014, the FERC granted authorization to allow NSTAR Electric to issue total short-term debt securities in an aggregate principal amount not to exceed $655 million outstanding at any one time, effective October 24, 2014 through October 23, 2016.

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, 2015, PSNH’s short-term debt authorization under the 10 percent of net fixed plant test plus $60 million totaled approximately $325 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, 2015, CL&P had $327.3 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.

Credit Agreements and Commercial Paper Programs: Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas are parties to a five-year $1.45 billion revolving credit facility. On October 26, 2015, this revolving credit facility was amended and restated and the termination date was extended to September 4, 2020. Under the revolving credit facility, CL&P has a borrowing sublimit of $600 million, and PSNH and WMECO each have borrowing sublimits of $300 million. The revolving credit facility serves to backstop Eversource parent’s $1.45 billion commercial paper program. The commercial paper program allows Eversource parent to issue commercial paper as a form of short-term debt. As of December 31, 2015 and 2014, Eversource parent had approximately $1.1 billion in short-term borrowings outstanding on each date under the Eversource parent commercial paper program, leaving $351.5 million and $348.9 million of available borrowing capacity as of December 31, 2015 and 2014, respectively. The weighted-average interest rate on these borrowings as of December 31, 2015 and 2014 was 0.72 percent and 0.43 percent, respectively. As of December 31, 2015, there were intercompany loans from Eversource parent of $277.4 million to CL&P, $231.3 million to PSNH and $143.4 million to WMECO. As of December 31, 2014, there were intercompany loans from Eversource parent of $133.4 million to CL&P, $90.5 million to PSNH and $21.4 million to WMECO.

NSTAR Electric has a five-year $450 million revolving credit facility. On October 26, 2015, this revolving credit facility was amended and restated and the termination date was extended to September 4, 2020. The facility serves to backstop NSTAR Electric’s $450 million commercial paper program. As of December 31, 2015 and 2014, NSTAR Electric had $62.5 million and $302 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $387.5 million and $148 million of available borrowing capacity as of December 31, 2015 and 2014, respectively. The weighted-average interest rate on these borrowings as of December 31, 2015 and 2014 was 0.40 percent and 0.27 percent, respectively.

Except as described below, amounts outstanding under the commercial paper programs 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. Intercompany loans from Eversource parent to CL&P, PSNH and WMECO are included in Notes Payable to Eversource Parent and are classified in current liabilities on their respective balance sheets. Intercompany loans from Eversource to CL&P, PSNH and WMECO are eliminated in consolidation on Eversource’s balance sheets.

On January 15, 2015, Eversource parent issued $150 million of 1.60 percent Series G Senior Notes due to mature in 2018 and $300 million of 3.15 percent Series H Senior Notes, due to mature in 2025. The proceeds, net of issuance costs, were used to repay short-term borrowings outstanding under the Eversource parent commercial paper program. As the debt proceeds, net of issuance costs, refinanced short-term debt, the short-term debt was classified as Long-Term Debt as of December 31, 2014. See Note 8, "Long-Term Debt," for further information on these debt issuances.

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, 2015 and 2014, 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)</td><td colspan="3">As of December 31,</td></tr><tr><td>2015</td><td>2014</td><td></td></tr><tr><td>First Mortgage Bonds:</td><td></td><td></td><td></td></tr><tr><td>7.875% 1994 Series D due 2024</td><td>$ 139.8</td><td>$ 139.8</td><td></td></tr><tr><td>5.750% 2004 Series B due 2034</td><td>130.0</td><td>130.0</td><td></td></tr><tr><td>5.000% 2005 Series A due 2015</td><td>-</td><td>100.0</td><td></td></tr><tr><td>5.625% 2005 Series B due 2035</td><td>100.0</td><td>100.0</td><td></td></tr><tr><td>6.350% 2006 Series A due 2036</td><td>250.0</td><td>250.0</td><td></td></tr><tr><td>5.375% 2007 Series A due 2017</td><td>150.0</td><td>150.0</td><td></td></tr><tr><td>5.750% 2007 Series B due 2037</td><td>150.0</td><td>150.0</td><td></td></tr><tr><td>5.775% 2007 Series C due 2017</td><td>100.0</td><td>100.0</td><td></td></tr><tr><td>6.375% 2007 Series D due 2037</td><td>100.0</td><td>100.0</td><td></td></tr><tr><td>5.650% 2008 Series A due 2018</td><td>300.0</td><td>300.0</td><td></td></tr><tr><td>5.500% 2009 Series A due 2019</td><td>250.0</td><td>250.0</td><td></td></tr><tr><td>2.500% 2013 Series A due 2023</td><td>400.0</td><td>400.0</td><td></td></tr><tr><td>4.300% 2014 Series A due 2044</td><td>250.0</td><td>250.0</td><td></td></tr><tr><td>4.150% 2015 Series A due 2045</td><td>350.0</td><td>-</td><td></td></tr><tr><td>Total First Mortgage Bonds</td><td>2,669.8</td><td>2,419.8</td><td></td></tr><tr><td>Pollution Control Revenue Bonds:</td><td></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><td></td></tr><tr><td>1.550% Fixed Rate Tax Exempt due 2031</td><td>-</td><td>62.0</td><td></td></tr><tr><td>Total Pollution Control Revenue Bonds</td><td>120.5</td><td>182.5</td><td></td></tr><tr><td>Pre-1983 Spent Nuclear Fuel Obligation</td><td>-</td><td>244.5</td><td></td></tr><tr><td>Less Amounts due Within One Year</td><td>-</td><td>(162.0)</td><td></td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>(10.7)</td><td>(4.8)</td><td></td></tr><tr><td>Unamortized Debt Issuance Costs(1)</td><td>(15.9)</td><td>(15.8)</td><td></td></tr><tr><td>CL&amp;P Long-Term Debt(1)</td><td>$ 2,763.7</td><td>$ 2,664.2</td><td></td></tr></table>

<table><tr><td>(Nillions of Dollars)</td><td>2015</td><td>2014</td></tr><tr><td>Debentures:</td><td></td><td></td></tr><tr><td>5.750% due 2036</td><td>$ 200.0</td><td>$ 200.0</td></tr><tr><td>5.625% due 2017</td><td>400.0</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>Variable Rate due 2016 (0.6036% and 0.4721% as of December 31, 2015 and 2014)</td><td>200.0</td><td>200.0</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>-</td></tr><tr><td>Total Debentures</td><td>2,050.0</td><td>1,800.0</td></tr></table>

<table><tr><td>PSNH(Millions of Dollars)</td><td>As of December 31,</td><td></td></tr><tr><td>First Mortgage Bonds:</td><td>2015</td><td>2014</td></tr><tr><td>5.60% Series M due 2035</td><td>$ 50.0</td><td>$ 50.0</td></tr><tr><td>6.15% Series N due 2017</td><td>70.0</td><td>70.0</td></tr><tr><td>6.00% Series O due 2018</td><td>110.0</td><td>110.0</td></tr><tr><td>4.50% Series P due 2019</td><td>150.0</td><td>150.0</td></tr><tr><td>4.05% Series Q due 2021</td><td>122.0</td><td>122.0</td></tr><tr><td>3.20% Series R due 2021</td><td>160.0</td><td>160.0</td></tr><tr><td>3.50% Series S due 2023</td><td>325.0</td><td>325.0</td></tr><tr><td>Total First Mortgage Bonds</td><td>987.0</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</td><td></td><td></td></tr><tr><td>(0.193% and 0.175% as of December 31, 2015 and 2014)</td><td>89.3</td><td>89.3</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>0.1</td><td>-</td></tr><tr><td>Unamortized Debt Issuance Costs(1)</td><td>(5.4)</td><td>(6.3)</td></tr><tr><td>PSNH Long-Term Debt(1)</td><td>$ 1,071.0</td><td>$ 1,070.0</td></tr></table>



<table><tr><td rowspan="2">WMECO(Millions of Dollars)</td><td colspan="2">As of December 31,</td></tr><tr><td>2015</td><td>2014</td></tr><tr><td>Notes:</td><td></td><td></td></tr><tr><td>5.90% Senior Notes Series B, due 2034</td><td>$ 50.0</td><td>$ 50.0</td></tr><tr><td>5.24% Senior Notes Series C, due 2015</td><td>-</td><td>50.0</td></tr><tr><td>6.70% Senior Notes Series D, due 2037</td><td>40.0</td><td>40.0</td></tr><tr><td>5.10% Senior Notes Series E, due 2020</td><td>95.0</td><td>95.0</td></tr><tr><td>3.50% Senior Notes Series F, due 2021</td><td>250.0</td><td>250.0</td></tr><tr><td>3.88% Senior Notes Series G, due 2023</td><td>80.0</td><td>80.0</td></tr><tr><td>Total Notes</td><td>515.0</td><td>565.0</td></tr><tr><td>Pre-1983 Spent Nuclear Fuel Obligation</td><td>-</td><td>57.4</td></tr><tr><td>Less Amounts due Within One Year</td><td>-</td><td>(50.0)</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>5.2</td><td>6.1</td></tr><tr><td>Unamortized Debt Issuance Costs (1)</td><td>(2.9)</td><td>(3.3)</td></tr><tr><td>WMECO Long-Term Debt (1)</td><td>$ 517.3</td><td>$ 575.2</td></tr></table>

<table><tr><td>(Millions of Dollars)</td><td>2015</td><td>2014</td></tr><tr><td>Yankee Gas - First Mortgage Bonds:</td><td></td><td></td></tr><tr><td>8.48% Series B due 2022</td><td>$ 20.0</td><td>$ 20.0</td></tr><tr><td>5.26% Series H due 2019</td><td>50.0</td><td>50.0</td></tr><tr><td>5.35% Series I due 2035</td><td>50.0</td><td>50.0</td></tr><tr><td>6.90% Series J due 2018</td><td>100.0</td><td>100.0</td></tr><tr><td>4.87% Series K due 2020</td><td>50.0</td><td>50.0</td></tr><tr><td>4.82% Series L due 2044</td><td>100.0</td><td>100.0</td></tr><tr><td>3.35% Series M due 2025</td><td>75.0</td><td>-</td></tr><tr><td>Total First Mortgage Bonds</td><td>445.0</td><td>370.0</td></tr><tr><td>Unamortized Premium</td><td>0.4</td><td>0.6</td></tr><tr><td>Unamortized Debt Issuance Costs (1)</td><td>(1.7)</td><td>(1.5)</td></tr><tr><td>Yankee Gas Long-Term Debt (1)</td><td>443.7</td><td>369.1</td></tr><tr><td>NSTAR Gas - First Mortgage Bonds:</td><td></td><td></td></tr><tr><td>9.95% Series J due 2020</td><td>25.0</td><td>25.0</td></tr><tr><td>7.11% Series K due 2033</td><td>35.0</td><td>35.0</td></tr><tr><td>7.04% Series M due 2017</td><td>25.0</td><td>25.0</td></tr><tr><td>4.46% Series N due 2020</td><td>125.0</td><td>125.0</td></tr><tr><td>4.35% Series O due 2045</td><td>100.0</td><td>-</td></tr><tr><td>Total First Mortgage Bonds</td><td>310.0</td><td>210.0</td></tr><tr><td>Unamortized Debt Issuance Costs (1)</td><td>(0.8)</td><td>(0.6)</td></tr><tr><td>NSTAR Gas Long-Term Debt (1)</td><td>309.2</td><td>209.4</td></tr><tr><td>Eversource Parent - Notes and Debentures:</td><td></td><td></td></tr><tr><td>4.50% Debentures due 2019</td><td>350.0</td><td>350.0</td></tr><tr><td>1.45% Senior Notes Series E due 2018</td><td>300.0</td><td>300.0</td></tr><tr><td>2.80% Senior Notes Series F due 2023</td><td>450.0</td><td>450.0</td></tr><tr><td>1.60% Senior Notes Series G due 2018</td><td>150.0</td><td>-</td></tr><tr><td>3.15% Senior Notes Series H due 2025</td><td>300.0</td><td>-</td></tr><tr><td>Eversource Parent Commercial Paper Borrowings</td><td>-</td><td>446.3</td></tr><tr><td>Total Eversource Parent Notes and Debentures</td><td>1,550.0</td><td>1,546.3</td></tr><tr><td>Pre-1983 Spent Nuclear Fuel Obligation (CYAPC)</td><td>179.5</td><td>179.4</td></tr><tr><td>Fair Value Adjustment (2)</td><td>173.5</td><td>202.3</td></tr><tr><td>Less Fair Value Adjustment - Current Portion (2)</td><td>(28.9)</td><td>(28.9)</td></tr><tr><td>Unamortized Premiums and Discounts, Net</td><td>(1.3)</td><td>(1.2)</td></tr><tr><td>Unamortized Debt Issuance Costs (1)</td><td>(1.9)</td><td>1.1</td></tr><tr><td>Total Other Long-Term Debt (1)</td><td>2,623.8</td><td>2,477.5</td></tr><tr><td>Total Eversource Long-Term Debt (1)</td><td>8,805.6</td><td>8,568.4</td></tr></table>

(1) Effective December 31, 2015, the carrying amount of Long-Term Debt includes unamortized debt issuance costs presented as a direct reduction from the carrying amount of the debt liability, in accordance with new accounting guidance. The December 31, 2014 carrying amount of Long-Term Debt was retrospectively adjusted to conform to the current year presentation. See Note 1C, “Summary of Significant Accounting Policies – Accounting Standards,” for further information.

(2) 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 merger.

Long-Term Debt Issuances: On January 15, 2015, Eversource parent issued $150 million of 1.60 percent Series G Senior Notes, due to mature in 2018, and $300 million of 3.15 percent Series H Senior Notes, due to mature in 2025. As the debt proceeds, net of issuance costs, refinanced short-term debt, the short-term debt was classified as Long-Term Debt as of December 31, 2014. On May 20, 2015 and December 1, 2015, CL&P issued $300 million and $50 million, respectively, of 4.15 percent 2015 Series A First and Refunding Mortgage Bonds due to mature in 2045. On September 10, 2015, Yankee Gas issued $75 million of 3.35 percent 2015 Series M First Mortgage Bonds due to mature in 2025. On November 18, 2015, NSTAR Electric issued $250 million of 3.25 percent debentures, due to mature in 2025. On December 8, 2015, NSTAR Gas issued $100



million of 4.35 percent Series O First Mortgage Bonds due to mature in 2045. The proceeds of all debt issuances, net of issuance costs, were used to repay short-term borrowings and fund capital expenditures and working capital.

Long-Term Debt Repayments: On April 1, 2015, CL&P repaid at maturity the $100 million 5.00 percent 2005 Series A First and Refunding Mortgage Bonds and also redeemed the $62 million 1996A Series 1.55 percent PCRBs that were subject to mandatory tender using short-term borrowings. On August 3, 2015, WMECO repaid at maturity the $50 million 5.24 percent Series C Senior Notes, using short-term borrowings.

Long-Term Debt Issuance Authorizations: On November 25, 2015, PURA approved Yankee Gas' request to extend the authorization period for issuance of up to $125 million in long-term debt from December 31, 2015 to December 31, 2016. On December 4, 2015, the DPU authorized WMECO to issue up to $100 million in long-term debt for the period through December 31, 2016. On December 4, 2015, the DPU approved NSTAR Electric's request to extend the authorization period for issuance of up to $250 million in long-term debt from December 31, 2015 to December 31, 2016.

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, NSTAR Electric and WMECO 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 a minimum equity requirement for NSTAR Gas. Under the minimum equity requirement, the outstanding long-term debt of NSTAR Gas 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 $120.5 million 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.

Yankee Gas has certain long-term debt agreements that contain cross-default provisions. No other debt issuances contain cross-default provisions as of December 31, 2015.

Pre-1983 Spent Nuclear Fuel Obligation: Under the Nuclear Waste Policy Act of 1982, CL&P and WMECO were obligated to pay the DOE for the costs of disposal of pre-1983 spent nuclear fuel and high-level radioactive waste for the period prior to the sale of their ownership shares in the Millstone nuclear power stations, which were sold in March 2001. The DOE is responsible for the selection and development of repositories for, and the disposal of, spent nuclear fuel and high-level radioactive waste. After the sale of the Millstone nuclear power stations in March 2001, CL&P and WMECO remained responsible for their share of the disposal costs for nuclear fuel used to generate electricity prior to April 7, 1983 (pre-1983 Spent Nuclear Fuel) and recorded an accrual for the full liability thereof to the DOE. This liability accrued interest costs at the 3-month Treasury bill yield rate. As of December 31, 2014, CL&P and WMECO's pre-1983 Spent Nuclear Fuel obligation was $244.5 million and $57.4 million, respectively, which included accumulated interest costs of $178 million for CL&P and $41.8 million for WMECO.

In late 2015, CL&P and WMECO made payments of $244.6 million and $57.4 million, respectively, to fully satisfy their pre-1983 Spent Nuclear Fuel obligations to the DOE, which included accumulated interest of $178 million and $41.8 million, respectively. CL&P issued debt to fund its payment while WMECO liquidated its spent nuclear fuel trust.

In addition, as a result of consolidating CYAPC, Eversource has consolidated $179.5 million and $179.4 million, respectively, in additional pre-1983 spent nuclear fuel obligations to the DOE, which include accumulated interest costs of $130.7 million and $130.6 million as of December 31, 2015 and 2014, 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 2016 through 2020 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, 2015:

<table><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td></tr><tr><td>2016</td><td>$ 200.0</td><td>$ -</td><td>$ 200.0</td><td>$ -</td><td>$ -</td></tr><tr><td>2017</td><td>745.0</td><td>250.0</td><td>400.0</td><td>70.0</td><td>-</td></tr><tr><td>2018</td><td>960.0</td><td>300.0</td><td>-</td><td>110.0</td><td>-</td></tr><tr><td>2019</td><td>800.0</td><td>250.0</td><td>-</td><td>150.0</td><td>-</td></tr><tr><td>2020</td><td>295.0</td><td>-</td><td>-</td><td>-</td><td>95.0</td></tr><tr><td>Thereafter</td><td>5,736.6</td><td>1,990.3</td><td>1,450.0</td><td>746.3</td><td>420.0</td></tr><tr><td>Total</td><td>$ 8,736.6</td><td>$ 2,790.3</td><td>$ 2,050.0</td><td>$ 1,076.3</td><td>$ 515.0</td></tr></table>



## 9. EMPLOYEE BENEFITS

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

As of December 31, 2014, Eversource Service sponsored two defined benefit retirement plans that covered eligible employees, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO. Effective January 1, 2015, these two pension plans were merged into one plan, sponsored by Eversource Service (Pension Plan). The Pension Plan is subject to the provisions of ERISA, as amended by the PPA of 2006. Eversource’s policy is to annually fund the Pension Plan in an amount at least equal to an amount that will satisfy all federal funding requirements. In addition to the Pension Plan, Eversource maintains non-qualified defined benefit retirement plans sponsored by Eversource Service (herein collectively referred to as the SERP Plans), which provide benefits in excess of Internal Revenue Code limitations to eligible current and retired participants.

As of December 31, 2014, Eversource Service also sponsored defined benefit postretirement plans that provided certain retiree benefits, primarily medical, dental and life insurance, to retired employees that met certain age and service eligibility requirements, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO. Effective January 1, 2015, these postretirement plans were merged into one plan, sponsored by Eversource Service (PBOP Plan). Under certain circumstances, eligible retirees are required to contribute to the costs of postretirement benefits. The benefits provided under the PBOP Plan 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 14, “Accumulated Other Comprehensive Income/(Loss),” to the financial statements.

For the year ended December 31, 2015, the difference between the actual return and calculated expected return on plan assets for the Pension and PBOP Plans are 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: On January 1, 2014, NSTAR Electric & Gas was merged into Eversource Service (service company merger) and, concurrently, all employees were transferred to the company they predominantly provide services for: Eversource Service, NSTAR Electric or NSTAR Gas. As a result of these employee transfers, the pension and SERP assets and liabilities of NSTAR Electric & Gas were attributed by participant and transferred to the applicable operating company’s balance sheets. This change had no impact on the income statement or net assets of NSTAR Electric or Eversource.

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 tables provide information on the Pension and SERP Plan benefit obligations, fair values of Pension Plan assets, and funded status:

<table><tr><td rowspan="3">Eversource (Millions of Dollars)</td><td colspan="3">Pension and SERP</td></tr><tr><td colspan="2">As of December 31,</td><td></td></tr><tr><td>2015</td><td>2014</td><td></td></tr><tr><td>Change in Benefit Obligation</td><td></td><td></td><td></td></tr><tr><td>Benefit Obligation as of Beginning of Year</td><td>$ (5,486.2)</td><td>$ (4,676.5)</td><td></td></tr><tr><td>Service Cost</td><td>(91.4)</td><td>(79.9)</td><td></td></tr><tr><td>Interest Cost</td><td>(227.0)</td><td>(225.7)</td><td></td></tr><tr><td>Actuarial Gain/(Loss)</td><td>331.5</td><td>(739.6)</td><td></td></tr><tr><td>Benefits Paid - Pension</td><td>238.5</td><td>230.3</td><td></td></tr><tr><td>Benefits Paid - Lump Sum</td><td>149.5</td><td>-</td><td></td></tr><tr><td>Benefits Paid - SERP</td><td>5.0</td><td>5.2</td><td></td></tr><tr><td>Benefit Obligation as of End of Year</td><td>$ (5,080.1)</td><td>$ (5,486.2)</td><td></td></tr><tr><td>Change in Pension Plan Assets</td><td></td><td></td><td></td></tr><tr><td>Fair Value of Pension Plan Assets as of Beginning of Year</td><td>$ 4,126.5</td><td>$ 3,985.9</td><td></td></tr><tr><td>Employer Contributions</td><td>154.6</td><td>171.6</td><td></td></tr><tr><td>Actual Return on Pension Plan Assets</td><td>12.3</td><td>199.3</td><td></td></tr><tr><td>Benefits Paid</td><td>(238.5)</td><td>(230.3)</td><td></td></tr><tr><td>Benefits Paid - Lump Sum</td><td>(149.5)</td><td>-</td><td></td></tr><tr><td>Fair Value of Pension Plan Assets as of End of Year</td><td>$ 3,905.4</td><td>$ 4,126.5</td><td></td></tr><tr><td>Funded Status as of December 31st</td><td>$ (1,174.7)</td><td>$ (1,359.7)</td><td></td></tr></table>



<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="9">Pension and SERP</td></tr><tr><td colspan="5">As of December 31, 2015</td><td colspan="4">As of December 31, 2014</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td></td></tr><tr><td>Change in Benefit Obligation</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Benefit Obligation as of Beginning of Year</td><td>$ (1,230.1)</td><td>$ (982.6)</td><td>$ (580.7)</td><td>$ (249.4)</td><td>$ (1,083.4)</td><td>$ (1,353.3)</td><td>$ (529.0)</td><td>$ (223.9)</td><td></td></tr><tr><td>Change due to transfer of employees</td><td>(4.6)</td><td>6.2</td><td>(1.9)</td><td>(1.3)</td><td>26.4</td><td>479.9</td><td>32.2</td><td>6.2</td><td></td></tr><tr><td>Service Cost</td><td>(24.7)</td><td>(14.9)</td><td>(12.1)</td><td>(4.3)</td><td>(20.2)</td><td>(13.6)</td><td>(9.7)</td><td>(3.5)</td><td></td></tr><tr><td>Interest Cost</td><td>(51.1)</td><td>(40.2)</td><td>(24.3)</td><td>(10.4)</td><td>(50.5)</td><td>(41.3)</td><td>(23.8)</td><td>(10.3)</td><td></td></tr><tr><td>Actuarial Gain/(Loss)</td><td>77.8</td><td>34.1</td><td>38.9</td><td>12.6</td><td>(161.0)</td><td>(107.0)</td><td>(73.3)</td><td>(29.8)</td><td></td></tr><tr><td>Benefits Paid - Pension</td><td>60.2</td><td>47.6</td><td>23.2</td><td>12.7</td><td>58.3</td><td>52.4</td><td>22.8</td><td>11.9</td><td></td></tr><tr><td>Benefits Paid - Lump Sum</td><td>14.5</td><td>-</td><td>9.1</td><td>2.5</td><td>-</td><td>-</td><td>-</td><td>-</td><td></td></tr><tr><td>Benefits Paid - SERP</td><td>0.4</td><td>0.1</td><td>0.2</td><td>-</td><td>0.3</td><td>0.3</td><td>0.1</td><td>-</td><td></td></tr><tr><td>Benefit Obligation as of End of Year</td><td>$ (1,157.6)</td><td>$ (949.7)</td><td>$ (547.6)</td><td>$ (237.6)</td><td>$ (1,230.1)</td><td>$ (982.6)</td><td>$ (580.7)</td><td>$ (249.4)</td><td></td></tr><tr><td>Change in Pension Plan Assets</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Fair Value of Pension Plan Assets as of Beginning of Year</td><td>$ 980.8</td><td>$ 879.0</td><td>$ 498.4</td><td>$ 234.0</td><td>$ 1,016.3</td><td>$ 1,235.3</td><td>$ 528.6</td><td>$ 240.4</td><td></td></tr><tr><td>Change due to transfer of employees</td><td>4.6</td><td>(6.2)</td><td>1.9</td><td>1.3</td><td>(26.4)</td><td>(441.4)</td><td>(32.2)</td><td>(6.2)</td><td></td></tr><tr><td>Employer Contributions</td><td>-</td><td>5.0</td><td>1.0</td><td>-</td><td>-</td><td>101.0</td><td>-</td><td>-</td><td></td></tr><tr><td>Actual Return on Pension Plan Assets</td><td>2.8</td><td>2.7</td><td>1.5</td><td>0.7</td><td>49.2</td><td>36.5</td><td>24.8</td><td>11.7</td><td></td></tr><tr><td>Benefits Paid</td><td>(60.2)</td><td>(47.6)</td><td>(23.2)</td><td>(12.7)</td><td>(58.3)</td><td>(52.4)</td><td>(22.8)</td><td>(11.9)</td><td></td></tr><tr><td>Benefits Paid - Lump Sum</td><td>(14.5)</td><td>-</td><td>(9.1)</td><td>(2.5)</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>$ 913.5</td><td>$ 832.9</td><td>$ 470.5</td><td>$ 220.8</td><td>$ 980.8</td><td>$ 879.0</td><td>$ 498.4</td><td>$ 234.0</td><td></td></tr><tr><td>Funded Status as of December 31st</td><td>$ (244.1)</td><td>$ (116.8)</td><td>$ (77.1)</td><td>$ (16.8)</td><td>$ (249.3)</td><td>$ (103.6)</td><td>$ (82.3)</td><td>$ (15.4)</td><td></td></tr></table>

In August 2015, Eversource made a total lump-sum payout of $149.5 million, which reduced the projected benefit obligation and Pension Plan assets by a corresponding amount. Therefore, the lump-sum payment had no impact on the net Accrued Pension Liability reflected on the Eversource, CL&P, PSNH and WMECO balance sheets as of December 31, 2015.

During 2014, the Society of Actuaries released a series of updated mortality tables resulting from studies that measured mortality rates for various groups of individuals. The updated mortality tables released in 2014 increased the life expectancy of plan participants by three to five years and had the effect of increasing the estimated benefits to be provided to plan participants. The impact of adopting the updated mortality tables on Eversource’s liability as of December 31, 2014 was an increase of approximately $340 million. In 2015, 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 new mortality scale resulted in a decrease of $48 million on Eversource’s liability as of December 31, 2015.

The increase in the discount rate used to calculate the funded status resulted in a decrease on Eversource’s liability of approximately $267 million as of December 31, 2015. Decreases in the discount rates resulted in an increase on Eversource’s liability of approximately $530 million as of December 31, 2014.

The pension and SERP Plans’ funded status includes the current portion of the SERP liability, which is included in Other Current Liabilities on the accompanying balance sheets.

As of December 31, 2015 and 2014, 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><td>WMECO</td></tr><tr><td>2015</td><td>$ 4,733.2</td><td>$ 1,062.7</td><td>$ 888.8</td><td>$ 506.4</td><td>$ 222.3</td></tr><tr><td>2014</td><td>5,000.1</td><td>1,101.4</td><td>910.4</td><td>524.5</td><td>226.4</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>2015</td><td>2014</td><td></td></tr><tr><td>Discount Rate</td><td>4.21</td><td>% - 4.60</td><td>%</td></tr><tr><td>Compensation/Progression Rate</td><td>3.50%</td><td></td><td>3.50%</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. For the year ended December 31, 2013 (prior to the service company merger), the net periodic pension expense recorded at NSTAR Electric represented the full cost of the plan with a portion of the costs allocated to affiliated companies based on participant demographic data.



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 portion of pension and SERP amounts are included in Operations and Maintenance expense on the statements of income. Capitalized pension 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, PSNH and WMECO 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"></td><td colspan="6">Pension and SERP</td></tr><tr><td colspan="6">For the Year Ended December 31, 2015</td></tr><tr><td></td><td colspan="3">NSTAR</td><td colspan="3">WMECO</td></tr><tr><td>(Millions of Dollars)</td><td>Eversource (1)</td><td>CL&amp;P</td><td>Electric</td><td>PSNH (1)</td><td></td><td></td></tr><tr><td>Service Cost</td><td>$ 91.4</td><td>$ 24.7</td><td>$ 14.9</td><td>$ 12.1</td><td>$ 4.3</td><td></td></tr><tr><td>Interest Cost</td><td>227.0</td><td>51.1</td><td>40.2</td><td>24.3</td><td>10.4</td><td></td></tr><tr><td>Expected Return on Pension Plan Assets</td><td>(335.9)</td><td>(78.9)</td><td>(70.0)</td><td>(40.4)</td><td>(18.9)</td><td></td></tr><tr><td>Actuarial Loss</td><td>148.5</td><td>32.2</td><td>35.8</td><td>11.6</td><td>6.4</td><td></td></tr><tr><td>Prior Service Cost/(Credit)</td><td>3.7</td><td>1.5</td><td>(0.1)</td><td>0.5</td><td>0.3</td><td></td></tr><tr><td>Total Net Periodic Benefit Expense</td><td>$ 134.7</td><td>$ 30.6</td><td>$ 20.8</td><td>$ 8.1</td><td>$ 2.5</td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 22.5</td><td>$ 13.6</td><td>$ 6.7</td><td>$ 4.4</td><td></td></tr><tr><td>Capitalized Pension Expense</td><td>$ 41.0</td><td>$ 18.8</td><td>$ 11.4</td><td>$ 3.5</td><td>$ 1.9</td><td></td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="6">Pension and SERP</td></tr><tr><td colspan="6">For the Year Ended December 31, 2014</td></tr><tr><td></td><td colspan="3">NSTAR</td><td colspan="3">WMECO</td></tr><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td></td><td></td></tr><tr><td>Service Cost</td><td>$ 79.9</td><td>$ 20.2</td><td>$ 13.6</td><td>$ 9.7</td><td>$ 3.5</td><td></td></tr><tr><td>Interest Cost</td><td>225.7</td><td>50.5</td><td>41.3</td><td>23.8</td><td>10.3</td><td></td></tr><tr><td>Expected Return on Pension Plan Assets</td><td>(310.8)</td><td>(75.4)</td><td>(63.0)</td><td>(38.1)</td><td>(17.9)</td><td></td></tr><tr><td>Actuarial Loss</td><td>128.4</td><td>33.7</td><td>23.5</td><td>11.6</td><td>6.9</td><td></td></tr><tr><td>Prior Service Cost</td><td>4.4</td><td>1.8</td><td>-</td><td>0.7</td><td>0.4</td><td></td></tr><tr><td>Total Net Periodic Benefit Expense</td><td>$ 127.6</td><td>$ 30.8</td><td>$ 15.4</td><td>$ 7.7</td><td>$ 3.2</td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 26.7</td><td>$ 10.4</td><td>$ 7.6</td><td>$ 5.1</td><td></td></tr><tr><td>Capitalized Pension Expense</td><td>$ 35.2</td><td>$ 17.6</td><td>$ 7.9</td><td>$ 3.0</td><td>$ 2.4</td><td></td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="6">Pension and SERP</td></tr><tr><td colspan="6">For the Year Ended December 31, 2013</td></tr><tr><td></td><td colspan="3">NSTAR</td><td colspan="3">WMECO</td></tr><tr><td>(Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>Electric (2)</td><td>PSNH</td><td></td><td></td></tr><tr><td>Service Cost</td><td>$ 102.3</td><td>$ 24.9</td><td>$ 33.1</td><td>$ 13.1</td><td>$ 4.7</td><td></td></tr><tr><td>Interest Cost</td><td>206.7</td><td>48.3</td><td>58.0</td><td>23.6</td><td>10.0</td><td></td></tr><tr><td>Expected Return on Pension Plan Assets</td><td>(278.1)</td><td>(73.8)</td><td>(84.4)</td><td>(35.4)</td><td>(17.4)</td><td></td></tr><tr><td>Actuarial Loss</td><td>210.5</td><td>55.9</td><td>58.1</td><td>21.6</td><td>11.8</td><td></td></tr><tr><td>Prior Service Cost/(Credit)</td><td>4.0</td><td>1.8</td><td>(0.3)</td><td>0.7</td><td>0.4</td><td></td></tr><tr><td>Total Net Periodic Benefit Expense</td><td>$ 245.4</td><td>$ 57.1</td><td>$ 64.5</td><td>$ 23.6</td><td>$ 9.5</td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 44.9</td><td>$ (8.4)</td><td>$ 10.5</td><td>$ 8.0</td><td></td></tr><tr><td>Capitalized Pension Expense</td><td>$ 73.2</td><td>$ 28.0</td><td>$ 28.9</td><td>$ 7.3</td><td>$ 5.2</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.

(2) NSTAR Electric’s allocated expense associated with the NSTAR SERP was $3.2 million for the year ended December 31, 2013 and was not included in the NSTAR Electric amounts in the table above. For the years ended December 31, 2015 and 2014, the SERP amount is now allocated to NSTAR Electric due to the service company merger.

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

Pension and SERP

<table><tr><td rowspan="2"></td><td colspan="3">For the Years Ended December 31,</td></tr><tr><td colspan="2">2015</td><td>2014</td></tr><tr><td>Discount Rate</td><td>4.20%</td><td>4.85%</td><td>- 5.03%</td></tr><tr><td>Expected Long-Term Rate of Return</td><td>8.25%</td><td>8.25%</td><td></td></tr><tr><td>Compensation/Progression Rate</td><td>3.50%</td><td>3.50%</td><td>- 4.00%</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 colspan="6">2015</td></tr><tr><td>Actuarial (Gains)/Losses Arising During the Year</td><td>$ (2.0)</td><td>$ 797.3</td><td>$ (6.2)</td><td>$ 55.9</td><td></td><td></td></tr><tr><td>Actuarial Losses Reclassified as Net Periodic Benefit Expense</td><td>(142.3)</td><td>(122.8)</td><td>(6.2)</td><td>(5.6)</td><td></td><td></td></tr><tr><td>Prior Service Cost Reclassified as Net Periodic Benefit Expense</td><td>(3.5)</td><td>(4.2)</td><td>(0.2)</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, 2015 and 2014, as well as the amounts that are expected to be recognized as components in 2016:

<table><tr><td rowspan="2"></td><td colspan="3">Regulatory Assets as of December 31,</td><td rowspan="2">Expected 2016 Expense</td><td colspan="3">AOCI as of December 31,</td><td rowspan="2">Expected 2016 Expense</td></tr><tr><td>2015</td><td>2014</td><td></td><td>2015</td><td>2014</td><td></td></tr><tr><td>(Millions of Dollars)</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>$ 1,667.6</td><td>$ 1,811.9</td><td>$ 120.6</td><td>$ 81.1</td><td>$ 93.5</td><td>$ 5.4</td><td></td><td></td></tr><tr><td>Prior Service Cost</td><td>9.7</td><td>13.2</td><td>3.4</td><td>0.6</td><td>0.8</td><td>0.2</td><td></td><td></td></tr></table>

PBOP Plan: On January 1, 2014, concurrent with the service company merger, the PBOP assets and liabilities of NSTAR Electric & Gas were attributed by participant and transferred to the applicable operating company's balance sheets. This change had no impact on the income statements or net assets of NSTAR Electric or Eversource. The PBOP Plan is accounted for under the multiple-employer approach, with each operating company's balance sheet reflecting its share of the funded status of the plan. The following tables provide information on the PBOP Plan benefit obligations, fair values of plan assets, and funded status:

<table><tr><td rowspan="3">Eversource (Millions of Dollars)</td><td colspan="3">PBOP</td></tr><tr><td colspan="2">As of December 31,</td><td></td></tr><tr><td>2015</td><td>2014</td><td></td></tr><tr><td>Change in Benefit Obligation</td><td></td><td></td><td></td></tr><tr><td>Benefit Obligation as of Beginning of Year</td><td>$ (1,147.9)</td><td>$ (1,038.0)</td><td></td></tr><tr><td>Service Cost</td><td>(16.3)</td><td>(12.5)</td><td></td></tr><tr><td>Interest Cost</td><td>(47.2)</td><td>(49.5)</td><td></td></tr><tr><td>Actuarial Gain/(Loss)</td><td>106.0</td><td>(95.5)</td><td></td></tr><tr><td>Benefits Paid</td><td>54.0</td><td>47.6</td><td></td></tr><tr><td>Benefit Obligation as of End of Year</td><td>$ (1,051.4)</td><td>$ (1,147.9)</td><td></td></tr><tr><td>Change in Plan Assets</td><td></td><td></td><td></td></tr><tr><td>Fair Value of Plan Assets as of Beginning of Year</td><td>$ 862.6</td><td>$ 826.5</td><td></td></tr><tr><td>Actual Return on Plan Assets</td><td>(4.3)</td><td>43.7</td><td></td></tr><tr><td>Employer Contributions</td><td>7.9</td><td>40.0</td><td></td></tr><tr><td>Benefits Paid</td><td>(54.0)</td><td>(47.6)</td><td></td></tr><tr><td>Fair Value of Plan Assets as of End of Year</td><td>$ 812.2</td><td>$ 862.6</td><td></td></tr><tr><td>Funded Status as of December 31 \( ^{st} \)</td><td>$ (239.2)</td><td>$ (285.3)</td><td></td></tr></table>

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="12">As of December 31,</td></tr><tr><td colspan="6">2015</td><td colspan="6">2014</td></tr><tr><td colspan="3">NSTAR</td><td colspan="3">PSNH</td><td colspan="3">WMECO</td><td colspan="3">NSTAR</td></tr><tr><td>Change in Benefit Obligation</td><td>CL&amp;P</td><td>Electric</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>$ (173.9)</td><td>$ (468.7)</td><td>$ (91.8)</td><td>$ (36.6)</td><td>$ (180.4)</td><td>$ -</td><td>$ (93.5)</td><td>$ (38.7)</td><td></td><td></td><td></td><td></td></tr><tr><td>Change due to transfer of employees</td><td>0.1</td><td>2.3</td><td>(0.3)</td><td>-</td><td>3.7</td><td>(395.5)</td><td>4.3</td><td>1.0</td><td></td><td></td><td></td><td></td></tr><tr><td>Service Cost</td><td>(2.1)</td><td>(5.4)</td><td>(1.4)</td><td>(0.4)</td><td>(2.2)</td><td>(3.1)</td><td>(1.3)</td><td>(0.4)</td><td></td><td></td><td></td><td></td></tr><tr><td>Interest Cost</td><td>(7.2)</td><td>(19.0)</td><td>(3.9)</td><td>(1.5)</td><td>(8.1)</td><td>(19.4)</td><td>(4.3)</td><td>(1.7)</td><td></td><td></td><td></td><td></td></tr><tr><td>Actuarial Gain/(Loss)</td><td>7.2</td><td>59.1</td><td>3.6</td><td>1.5</td><td>3.5</td><td>(68.6)</td><td>(1.1)</td><td>1.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Benefits Paid</td><td>11.9</td><td>18.9</td><td>5.3</td><td>2.6</td><td>9.6</td><td>17.9</td><td>4.1</td><td>1.9</td><td></td><td></td><td></td><td></td></tr><tr><td>Benefit Obligation as of End of Year</td><td>$ (164.0)</td><td>$ (412.8)</td><td>$ (88.5)</td><td>$ (34.4)</td><td>$ (173.9)</td><td>$ (468.7)</td><td>$ (91.8)</td><td>$ (36.6)</td><td></td><td></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><td></td><td></td></tr><tr><td>Fair Value of Plan Assets as of Beginning of Year</td><td>$ 149.0</td><td>$ 336.5</td><td>$ 80.9</td><td>$ 34.4</td><td>$ 151.3</td><td>$ -</td><td>$ 81.8</td><td>$ 35.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Change due to transfer of employees</td><td>-</td><td>0.6</td><td>0.2</td><td>-</td><td>(3.2)</td><td>316.7</td><td>(3.1)</td><td>(1.0)</td><td></td><td></td><td></td><td></td></tr><tr><td>Actual Return on Plan Assets</td><td>(0.4)</td><td>(2.8)</td><td>-</td><td>(0.1)</td><td>6.3</td><td>18.4</td><td>3.8</td><td>1.6</td><td></td><td></td><td></td><td></td></tr><tr><td>Employer Contributions</td><td>-</td><td>4.9</td><td>-</td><td>-</td><td>4.2</td><td>19.3</td><td>2.5</td><td>0.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Benefits Paid</td><td>(11.9)</td><td>(18.9)</td><td>(5.3)</td><td>(2.6)</td><td>(9.6)</td><td>(17.9)</td><td>(4.1)</td><td>(1.9)</td><td></td><td></td><td></td><td></td></tr><tr><td>Fair Value of Plan Assets as of End of Year</td><td>$ 136.7</td><td>$ 320.3</td><td>$ 75.8</td><td>$ 31.7</td><td>$ 149.0</td><td>$ 336.5</td><td>$ 80.9</td><td>$ 34.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Funded Status as of December 31 \( ^{st} \)</td><td>$ (27.3)</td><td>$ (92.5)</td><td>$ (12.7)</td><td>$ (2.7)</td><td>$ (24.9)</td><td>$ (132.2)</td><td>$ (10.9)</td><td>$ (2.2)</td><td></td><td></td><td></td><td></td></tr></table>

During 2014, the Society of Actuaries released a series of updated mortality tables resulting from studies that measured mortality rates for various groups of individuals. The updated mortality tables released in 2014 increased the life expectancy of plan participants by three to five years and had the effect of increasing the estimated benefits to be provided to plan participants. The impact of adopting the updated mortality tables on Eversource’s liability as of December 31, 2014 was an increase of approximately $82 million. In 2015, 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 new mortality scale resulted in a decrease of $23 million on Eversource’s liability as of December 31, 2015.

The increase in the discount rate used to calculate the funded status resulted in a decrease on Eversource’s liability of approximately $60 million as of December 31, 2015. Decreases in the discount rates resulted in an increase on Eversource’s liability of approximately $110 million as of December 31, 2014.

The following actuarial assumptions were used in calculating the PBOP Plan’s year end funded status:

<table><tr><td rowspan="3"></td><td colspan="2">PBOP</td></tr><tr><td colspan="2">As of December 31,</td></tr><tr><td>2015</td><td>2014</td></tr><tr><td>Discount Rate</td><td>4.62%</td><td>4.22%</td></tr><tr><td>Health Care Cost Trend Rate</td><td>6.25%</td><td>6.50%</td></tr></table>

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. For the year ended December 31, 2013 (prior to the service company merger), the net periodic postretirement expense of the NSTAR PBOP Plan allocated to NSTAR Electric was $4.6 million.

The components of net periodic benefit expense for the PBOP Plan are shown below. The net periodic benefit expense and the intercompany allocations less the capitalized portion of PBOP are included in Operations and Maintenance 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, PSNH and WMECO 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="7">PBOP</td></tr><tr><td colspan="7">For the Year Ended December 31, 2015</td></tr><tr><td colspan="2">Eversource</td><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td><td>PSNH</td></tr><tr><td>Service Cost</td><td>$ 16.3</td><td>$ 2.1</td><td>$ 5.4</td><td>$ 1.4</td><td>$ 0.4</td><td></td><td></td></tr><tr><td>Interest Cost</td><td>47.2</td><td>7.2</td><td>19.0</td><td>3.9</td><td>1.5</td><td></td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(67.4)</td><td>(11.1)</td><td>(27.3)</td><td>(6.0)</td><td>(2.5)</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><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><td></td></tr><tr><td>Total Net Periodic Benefit Expense/(Income)</td><td>$ 2.4</td><td>$ (1.1)</td><td>$ (0.8)</td><td>$ (0.2)</td><td>$ (0.6)</td><td></td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 1.9</td><td>$ 0.8</td><td>$ 0.4</td><td>$ 0.3</td><td></td><td></td></tr><tr><td>Capitalized PBOP Expense/(Income)</td><td>$ 0.1</td><td>$ (0.2)</td><td>$ (0.2)</td><td>$ 0.2</td><td>$ (0.2)</td><td></td><td></td></tr><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="7">PBOP</td></tr><tr><td colspan="7">For the Year Ended December 31, 2014</td></tr><tr><td colspan="2">Eversource</td><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td><td>PSNH</td></tr><tr><td>Service Cost</td><td>$ 12.5</td><td>$ 2.2</td><td>$ 3.1</td><td>$ 1.3</td><td>$ 0.4</td><td></td><td></td></tr><tr><td>Interest Cost</td><td>49.5</td><td>8.1</td><td>19.4</td><td>4.3</td><td>1.7</td><td></td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(63.3)</td><td>(10.5)</td><td>(25.9)</td><td>(5.4)</td><td>(2.3)</td><td></td><td></td></tr><tr><td>Actuarial Loss/(Gain)</td><td>12.2</td><td>4.2</td><td>(0.5)</td><td>2.2</td><td>0.5</td><td></td><td></td></tr><tr><td>Prior Service Credit</td><td>(2.8)</td><td>-</td><td>(1.9)</td><td>-</td><td>-</td><td></td><td></td></tr><tr><td>Total Net Periodic Benefit Expense/(Income)</td><td>$ 8.1</td><td>$ 4.0</td><td>$ (5.8)</td><td>$ 2.4</td><td>$ 0.3</td><td></td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 3.8</td><td>$ 0.8</td><td>$ 1.0</td><td>$ 0.7</td><td></td><td></td></tr><tr><td>Capitalized PBOP Expense/(Income)</td><td>$ 1.4</td><td>$ 1.8</td><td>$ (2.3)</td><td>$ 0.8</td><td>$ 0.2</td><td></td><td></td></tr><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="7">PBOP</td></tr><tr><td colspan="7">For the Year Ended December 31, 2013</td></tr><tr><td colspan="2">Eversource</td><td colspan="2">CL&amp;P</td><td colspan="2">PSNH</td><td>WMECO</td></tr><tr><td>Service Cost</td><td>$ 16.9</td><td>$ 3.4</td><td>$ 2.3</td><td>$ 0.7</td><td></td><td></td><td></td></tr><tr><td>Interest Cost</td><td>47.2</td><td>7.9</td><td>4.0</td><td>1.7</td><td></td><td></td><td></td></tr><tr><td>Expected Return on Plan Assets</td><td>(55.4)</td><td>(10.1)</td><td>(5.2)</td><td>(2.3)</td><td></td><td></td><td></td></tr><tr><td>Actuarial Loss</td><td>26.0</td><td>7.4</td><td>3.6</td><td>1.1</td><td></td><td></td><td></td></tr><tr><td>Prior Service Credit</td><td>(2.1)</td><td>-</td><td>-</td><td>-</td><td></td><td></td><td></td></tr><tr><td>Total Net Periodic Benefit Expense</td><td>$ 32.6</td><td>$ 8.6</td><td>$ 4.7</td><td>$ 1.2</td><td></td><td></td><td></td></tr><tr><td>Intercompany Allocations</td><td>N/A</td><td>$ 7.1</td><td>$ 1.6</td><td>$ 1.3</td><td></td><td></td><td></td></tr><tr><td>Capitalized PBOP Expense</td><td>$ 8.8</td><td>$ 3.9</td><td>$ 1.3</td><td>$ 0.6</td><td></td><td></td><td></td></tr></table>



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

<table><tr><td rowspan="2"></td><td colspan="4">PBOP</td></tr><tr><td colspan="4">For the Years Ended December 31,</td></tr><tr><td></td><td>2015</td><td>2014</td><td colspan="2">2013</td></tr><tr><td>Discount Rate</td><td>4.22 %</td><td>4.78 %</td><td>5.10 %</td><td>4.04 % - 4.35 %</td></tr><tr><td>Expected Long-Term Rate of Return</td><td>8.25 %</td><td>8.25 %</td><td></td><td>8.25%</td></tr></table>

As of December 31, 2015 and 2014, the health care cost trend rate assumptions used to determine the PBOP Plan’s funded status was 6.25 percent and 6.5 percent, respectively, subsequently decreasing to an ultimate rate of 4.5 percent in 2023. The health care cost trend rate assumption used to calculate the PBOP expense amount was 6.5 percent for the year ended December 31, 2015.

Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans. The effect of changing the assumed health care cost trend rate by one percentage point for the year ended December 31, 2015 would have the following effects:

<table><tr><td>(Millions of Dollars)</td><td>One Percentage Point Increase</td><td>One Percentage Point Decrease</td></tr><tr><td>Effect on PBOP Obligation</td><td>$ 115.3</td><td>$ (90.8)</td></tr><tr><td>Effect on Total Service and Interest Cost Components</td><td>8.5</td><td>(6.3)</td></tr></table>

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="2"></td><td colspan="2">Regulatory Assets</td><td colspan="2">OCI</td></tr><tr><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>(Millions of Dollars)</td><td>2015</td><td>2014</td><td>2015</td><td>2014</td></tr><tr><td>Actuarial (Gains)/Losses Arising During the Year</td><td>$ (34.1)</td><td>$ 115.1</td><td>$ 0.7</td><td>$ 0.4</td></tr><tr><td>Actuarial Losses Reclassified as Net Periodic Benefit Expense</td><td>(6.4)</td><td>(11.6)</td><td>(0.4)</td><td>(0.6)</td></tr><tr><td>Prior Service Credit Reclassified as Net Periodic Benefit Income</td><td>0.5</td><td>2.8</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, 2015 and 2014, as well as the amounts that are expected to be recognized as components in 2016:

<table><tr><td rowspan="2"></td><td colspan="2">Regulatory Assets as of December 31,</td><td colspan="2">Expected 2016</td><td colspan="2">AOCI as of December 31,</td><td colspan="2">Expected 2016</td></tr><tr><td>2015</td><td>2014</td><td>Expense</td><td>2015</td><td>2014</td><td>Expense</td><td>2015</td><td>2014</td></tr><tr><td>Actuarial Loss</td><td>$ 152.2</td><td>$ 192.7</td><td>$ 4.0</td><td>$ 6.3</td><td>$ 6.0</td><td>$ 0.4</td><td></td><td></td></tr><tr><td>Prior Service Credit</td><td>(1.3)</td><td>(1.8)</td><td>(0.2)</td><td>-</td><td>-</td><td>-</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>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>2021-2025</td></tr><tr><td>Pension and SERP</td><td>$ 253.5</td><td>$ 272.9</td><td>$ 273.9</td><td>$ 283.7</td><td>$ 292.7</td><td>$ 1,604.3</td></tr><tr><td>PBOP</td><td>60.8</td><td>61.2</td><td>61.4</td><td>61.8</td><td>62.4</td><td>315.4</td></tr></table>

Eversource Contributions: Eversource contributed $154.6 million to the Pension Plan in 2015, of which $5 million was contributed by NSTAR Electric, $1 million by PSNH and the remainder by other Eversource subsidiaries, primarily Eversource Service. Based on the current status of the Pension Plan and federal pension funding requirements, although not required to make a minimum pension contribution in 2016, Eversource currently expects to make contributions of approximately $146 million in 2016, of which $21 million will be contributed by NSTAR Electric and $17 million by PSNH. The remaining $108 million is expected to be contributed by other Eversource subsidiaries, primarily Eversource Service.

Eversource contributed $7.9 million to the PBOP Plan in 2015, of which $4.9 million was contributed by NSTAR Electric. Eversource expects to make approximately $9.5 million in contributions in 2016.



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 defined benefit 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, 2015, management has assumed long-term rates of return of 8.25 percent for the 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:

<table><tr><td rowspan="3"></td><td colspan="2">As of December 31, 2015</td><td colspan="2">As of December 31, 2014</td></tr><tr><td colspan="2">Pension Plan and Tax-Exempt Assets Within PBOP Plan</td><td colspan="2">Pension Plan and Tax-Exempt Assets Within PBOP Plan</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>22%</td><td>8.5%</td><td>24%</td><td>9%</td></tr><tr><td>International</td><td>13%</td><td>8.5%</td><td>10%</td><td>9%</td></tr><tr><td>Emerging Markets</td><td>5%</td><td>10%</td><td>6%</td><td>10%</td></tr><tr><td>Private Equity</td><td>12%</td><td>12%</td><td>10%</td><td>13%</td></tr><tr><td>Debt Securities:</td><td></td><td></td><td></td><td></td></tr><tr><td>Fixed Income</td><td>12%</td><td>4.5%</td><td>15%</td><td>5%</td></tr><tr><td>High Yield Fixed Income</td><td>13%</td><td>8.5%</td><td>9%</td><td>7.5%</td></tr><tr><td>Emerging Markets Debt</td><td>5%</td><td>7.5%</td><td>6%</td><td>7.5%</td></tr><tr><td>Real Estate and Other Assets</td><td>10%</td><td>7.5%</td><td>9%</td><td>7.5%</td></tr><tr><td>Hedge Funds</td><td>8%</td><td>7%</td><td>11%</td><td>7%</td></tr></table>

The taxable assets within the 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:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="10">Pension Plan</td></tr><tr><td colspan="6">2015</td><td colspan="4">2014</td></tr><tr><td>Level 1</td><td>Level 2</td><td>Level 3</td><td>Total</td><td>Level 1</td><td>Level 2</td><td>Level 3</td><td>Total</td><td></td><td></td></tr><tr><td>Equity Securities (1)</td><td>$ 396.5</td><td>$ 985.7</td><td>$ 305.2</td><td>$ 1,687.4</td><td>$ 414.7</td><td>$ 1,035.0</td><td>$ 292.2</td><td>$ 1,741.9</td><td></td><td></td></tr><tr><td>Private Equity</td><td>7.6</td><td>-</td><td>464.7</td><td>472.3</td><td>18.8</td><td>-</td><td>367.9</td><td>386.7</td><td></td><td></td></tr><tr><td>Fixed Income (2)</td><td>-</td><td>432.0</td><td>784.8</td><td>1,216.8</td><td>10.2</td><td>561.4</td><td>722.0</td><td>1,293.6</td><td></td><td></td></tr><tr><td>Real Estate and Other Assets</td><td>-</td><td>117.5</td><td>260.3</td><td>377.8</td><td>-</td><td>132.0</td><td>265.8</td><td>397.8</td><td></td><td></td></tr><tr><td>Hedge Funds</td><td>-</td><td>49.7</td><td>290.8</td><td>340.5</td><td>-</td><td>20.0</td><td>475.0</td><td>495.0</td><td></td><td></td></tr><tr><td>Total</td><td>$ 404.1</td><td>$ 1,584.9</td><td>$ 2,105.8</td><td>$ 4,094.8</td><td>$ 443.7</td><td>$ 1,748.4</td><td>$ 2,122.9</td><td>$ 4,315.0</td><td></td><td></td></tr><tr><td>Less: 401(h) PBOP Assets (3)</td><td></td><td></td><td></td><td>(189.4)</td><td></td><td></td><td></td><td></td><td></td><td>(188.5)</td></tr><tr><td>Total Pension Assets</td><td></td><td></td><td></td><td>$ 3,905.4</td><td></td><td></td><td></td><td></td><td>$ 4,126.5</td><td></td></tr></table>

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="10">PBP Plan</td></tr><tr><td colspan="6">2015</td><td colspan="4">2014</td></tr><tr><td>Level 1</td><td>Level 2</td><td>Level 3</td><td>Total</td><td>Level 1</td><td>Level 2</td><td>Level 3</td><td>Total</td><td></td><td></td></tr><tr><td>Equity Securities (1)</td><td>$ 109.7</td><td>$ 121.6</td><td>$ 77.8</td><td>$ 309.1</td><td>$ 104.1</td><td>$ 172.8</td><td>$ 75.1</td><td>$ 352.0</td><td></td><td></td></tr><tr><td>Private Equity</td><td>-</td><td>-</td><td>32.9</td><td>32.9</td><td>-</td><td>-</td><td>24.9</td><td>24.9</td><td></td><td></td></tr><tr><td>Fixed Income (2)</td><td>9.7</td><td>99.9</td><td>81.6</td><td>191.2</td><td>16.1</td><td>110.0</td><td>78.3</td><td>204.4</td><td></td><td></td></tr><tr><td>Real Estate and Other Assets</td><td>-</td><td>17.0</td><td>20.4</td><td>37.4</td><td>-</td><td>19.4</td><td>15.0</td><td>34.4</td><td></td><td></td></tr><tr><td>Hedge Funds</td><td>-</td><td>-</td><td>52.2</td><td>52.2</td><td>-</td><td>-</td><td>58.4</td><td>58.4</td><td></td><td></td></tr><tr><td>Total</td><td>$ 119.4</td><td>$ 238.5</td><td>$ 264.9</td><td>$ 622.8</td><td>$ 120.2</td><td>$ 302.2</td><td>$ 251.7</td><td>$ 674.1</td><td></td><td></td></tr><tr><td>Add: 401(h) PBOP Assets (3)</td><td></td><td></td><td></td><td>189.4</td><td></td><td></td><td></td><td></td><td>188.5</td><td></td></tr><tr><td>Total PBOP Assets</td><td></td><td></td><td></td><td>$ 812.2</td><td></td><td></td><td></td><td>$ 862.6</td><td></td><td></td></tr></table>

(1) United States, International and Emerging Markets equity securities classified as Level 2 include investments in commingled funds. Level 3 investments include hedge funds that are overlayed with equity index swaps and futures contracts and funds invested in equities that have redemption restrictions.

(2) Fixed Income investments classified as Level 3 investments include 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. Commingled funds included in Level 2 equity securities are recorded at the net asset value provided by the asset manager, which is based on the market prices of the underlying equity securities. 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. 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. Hedge funds and investments in opportunistic fixed income funds are recorded at net asset value based on the values of the underlying assets. The assets in the hedge funds and opportunistic fixed income funds are valued using observable inputs and are classified as Level 3 within the fair value hierarchy due to redemption restrictions. Private Equity investments and Real Estate and Other Assets are valued using the net asset value 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. These investments are classified as Level 3 due to redemption restrictions.

Fair Value Measurements Using Significant Unobservable Inputs (Level 3): The following tables present changes in the Level 3 category of Eversource’s Pension and PBOP Plan assets for the years ended December 31, 2015 and 2014:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="8">Pension Plan</td></tr><tr><td>Equity Securities</td><td>Private Equity</td><td>Fixed Income</td><td>Real Estate and Other Assets</td><td>Hedge Funds</td><td>Total</td><td></td><td></td></tr><tr><td>Balance as of January 1, 2014</td><td>$ 255.5</td><td>$ 300.3</td><td>$ 589.5</td><td>$ 288.5</td><td>$ 416.9</td><td>$ 1,850.7</td><td></td><td></td></tr><tr><td>Actual Return/(Loss) on Plan Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Relating to Assets Still Held as of Year End</td><td>(2.3)</td><td>14.0</td><td>45.2</td><td>(3.6)</td><td>23.5</td><td>76.8</td><td></td><td></td></tr><tr><td>Relating to Assets Distributed During the Year</td><td>-</td><td>13.9</td><td>(6.2)</td><td>28.3</td><td>(15.2)</td><td>20.8</td><td></td><td></td></tr><tr><td>Purchases, Sales and Settlements</td><td>39.0</td><td>39.7</td><td>93.5</td><td>(47.4)</td><td>49.8</td><td>174.6</td><td></td><td></td></tr><tr><td>Balance as of December 31, 2014</td><td>$ 292.2</td><td>$ 367.9</td><td>$ 722.0</td><td>$ 265.8</td><td>$ 475.0</td><td>$ 2,122.9</td><td></td><td></td></tr><tr><td>Transfer Between Categories</td><td>76.5</td><td>-</td><td>-</td><td>-</td><td>(76.5)</td><td>-</td><td></td><td></td></tr><tr><td>Actual Return/(Loss) on Plan Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Relating to Assets Still Held as of Year End</td><td>5.3</td><td>24.4</td><td>(6.7)</td><td>(7.1)</td><td>-</td><td>15.9</td><td></td><td></td></tr><tr><td>Relating to Assets Distributed During the Year</td><td>-</td><td>27.3</td><td>17.0</td><td>24.8</td><td>(0.9)</td><td>68.2</td><td></td><td></td></tr><tr><td>Purchases, Sales and Settlements</td><td>(68.8)</td><td>45.1</td><td>52.5</td><td>(23.2)</td><td>(106.8)</td><td>(101.2)</td><td></td><td></td></tr><tr><td>Balance as of December 31, 2015</td><td>$ 305.2</td><td>$ 464.7</td><td>$ 784.8</td><td>$ 260.3</td><td>$ 290.8</td><td>$ 2,105.8</td><td></td><td></td></tr></table>

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="8">PBP Plan</td></tr><tr><td>Equity Securities</td><td>Private Equity</td><td>Fixed Income</td><td>Real Estate and Other Assets</td><td>Hedge Funds</td><td>Total</td><td></td><td></td></tr><tr><td>Balance as of January 1, 2014</td><td>$ 69.1</td><td>$ 17.9</td><td>$ 51.5</td><td>$ 33.9</td><td>$ 57.0</td><td>$ 229.4</td><td></td><td></td></tr><tr><td>Actual Return/(Loss) on Plan Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Relating to Assets Still Held as of Year End</td><td>6.0</td><td>1.3</td><td>1.9</td><td>(2.8)</td><td>1.4</td><td>7.8</td><td></td><td></td></tr><tr><td>Relating to Assets Distributed During the Year</td><td>-</td><td>0.1</td><td>-</td><td>(2.2)</td><td>-</td><td>(2.1)</td><td></td><td></td></tr><tr><td>Purchases, Sales and Settlements</td><td>-</td><td>5.6</td><td>24.9</td><td>(13.9)</td><td>-</td><td>16.6</td><td></td><td></td></tr><tr><td>Balance as of December 31, 2014</td><td>$ 75.1</td><td>$ 24.9</td><td>$ 78.3</td><td>$ 15.0</td><td>$ 58.4</td><td>$ 251.7</td><td></td><td></td></tr><tr><td>Actual Return/(Loss) on Plan Assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Relating to Assets Still Held as of Year End</td><td>(2.0)</td><td>2.6</td><td>2.1</td><td>0.3</td><td>(1.5)</td><td>1.5</td><td></td><td></td></tr><tr><td>Relating to Assets Distributed During the Year</td><td>-</td><td>-</td><td>(0.3)</td><td>-</td><td>-</td><td>(0.3)</td><td></td><td></td></tr><tr><td>Purchases, Sales and Settlements</td><td>4.7</td><td>5.4</td><td>1.5</td><td>5.1</td><td>(4.7)</td><td>12.0</td><td></td><td></td></tr><tr><td>Balance as of December 31, 2015</td><td>$ 77.8</td><td>$ 32.9</td><td>$ 81.6</td><td>$ 20.4</td><td>$ 52.2</td><td>$ 264.9</td><td></td><td></td></tr></table>

## B. Defined Contribution Plans

Effective January 1, 2014, Eversource maintains one defined contribution plan on behalf of eligible participants, the Eversource 401k Plan. 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. Beginning in 2014 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 rowspan="2">(Millions of Dollars)</td><td colspan="6">NSTAR</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</td><td></td></tr><tr><td>2015</td><td>$ 30.4</td><td>$ 4.8</td><td>$ 6.3</td><td>$ 3.4</td><td>$ 1.0</td><td></td></tr><tr><td>2014</td><td>29.7</td><td>5.0</td><td>6.3</td><td>3.2</td><td>1.0</td><td></td></tr><tr><td>2013</td><td>37.0</td><td>5.1</td><td>8.5</td><td>3.3</td><td>1.0</td><td></td></tr></table>

Allocations of Eversource common shares were made from Eversource treasury shares to satisfy a portion of the Eversource 401k Plan obligation, which provides 100 percent of the matching contribution in Eversource common shares. For treasury shares used to satisfy the Eversource 401k Plan employer matching contributions, compensation expense is recognized equal to the fair value of shares that have been allocated to participants. Any difference between the fair value and the average cost of the allocated treasury shares is charged or credited to Capital Surplus, Paid In on the balance sheet. For the years ended December 31, 2015, 2014 and 2013, Eversource recognized $7 million, $22 million and $9.1 million, respectively, of compensation expense related to treasury shares used to satisfy the matching contribution.



## 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, PSNH and WMECO 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, PSNH and WMECO.

Eversource Incentive Plans: Eversource maintains long-term equity-based incentive plans in which Eversource, CL&P, NSTAR Electric, PSNH and WMECO 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, 2015 and 2014, Eversource had 3,005,010 and 3,112,020 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 - Stock options currently outstanding are fully vested.

- ESPP Shares - For shares sold under the ESPP, no compensation expense was recorded as the ESPP qualified as a non-compensatory plan. The ESPP ended as of February 1, 2016.

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 rowspan="2"></td><td>RSUs</td><td colspan="2">Weighted Average Grant-Date</td></tr><tr><td>(Units)</td><td colspan="2">Fair Value</td></tr><tr><td>Outstanding as of December 31, 2014</td><td>1,380,747</td><td>$</td><td>35.67</td></tr><tr><td>Granted</td><td>266,230</td><td>$</td><td>54.57</td></tr><tr><td>Shares issued</td><td>(888,495)</td><td>$</td><td>33.94</td></tr><tr><td>Forfeited</td><td>(29,174)</td><td>$</td><td>46.68</td></tr><tr><td>Outstanding as of December 31, 2015</td><td>729,308</td><td>$</td><td>43.45</td></tr></table>

The weighted average grant-date fair value of RSUs granted for the years ended December 31, 2015, 2014 and 2013 was $54.57, $42.27 and $39.56, respectively. As of December 31, 2015 and 2014, the number and weighted average grant-date fair value of unvested RSUs was 469,772 and $48.58 per share, and 1,024,729 and $38.14 per share, respectively. During 2015, there were 784,376 RSUs at a weighted average grant-date fair value of $37.21 per share that vested and were either paid or deferred. As of December 31, 2015, 259,536 RSUs were fully vested and deferred and an additional 446,283 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, 2014</td><td>375,644</td><td>$ 42.20</td></tr><tr><td>Granted</td><td>172,543</td><td>$ 55.04</td></tr><tr><td>Shares issued</td><td>(4,604)</td><td>$ 42.23</td></tr><tr><td>Forfeited</td><td>(15,155)</td><td>$ 45.33</td></tr><tr><td>Outstanding as of December 31, 2015</td><td>528,428</td><td>$ 46.30</td></tr></table>

The weighted average grant-date fair value of Performance Shares granted for the years ended December 31, 2015, 2014 and 2013 was $55.04, $43.40 and $40.96, respectively. As of December 31, 2015, all outstanding performance shares are unvested.



The total compensation expense and associated future income tax benefits recognized by Eversource, CL&P, NSTAR Electric, PSNH and WMECO for share-based compensation awards were as follows:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>Compensation Expense</td><td>$ 23.1</td><td>$ 24.6</td><td>$ 27.0</td><td></td></tr><tr><td>Future Income Tax Benefit</td><td>9.4</td><td>10.3</td><td>10.7</td><td></td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2"></td><td colspan="6">2015</td><td colspan="6">2014</td><td colspan="6">2013</td></tr><tr><td colspan="2">NSTAR Electric</td><td colspan="2">PSNH</td><td colspan="2">WMECO</td><td colspan="2">CL&amp;P Electric</td><td colspan="2">PSNH</td><td colspan="2">WMECO</td><td rowspan="2">CL&amp;P Electric</td><td colspan="2">PSNH</td><td colspan=2">WMECO</td><td></td></tr><tr><td>(Millions of Dollars)</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</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>$ 9.3</td><td>$ 5.8</td><td>$ 3.2</td><td>$ 1.7</td><td>$ 8.1</td><td>$ 7.4</td><td>$ 3.0</td><td>$ 1.3</td><td>$ 6.8</td><td>$ 7.5</td><td>$ 2.3</td><td>$ 1.3</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Future Income Tax Benefit</td><td>3.8</td><td>2.4</td><td>1.3</td><td>0.7</td><td>3.4</td><td>3.1</td><td>1.3</td><td>0.5</td><td>2.7</td><td>3.0</td><td>0.9</td><td>0.5</td><td></td><td></td><td></td><td></td><td></td><td></td></tr></table>

As of December 31, 2015, there was $14.9 million of total unrecognized compensation expense related to nonvested share-based awards for Eversource, including $6.1 million for CL&P, $3.8 million for NSTAR Electric, $2.2 million for PSNH and $1.2 million for WMECO. This cost is expected to be recognized ratably over a weighted-average period of 1.74 years for Eversource, and 1.73 years for each CL&P, NSTAR Electric, PSNH and WMECO.

For each of the years ended December 31, 2015 and 2014, changes in excess tax benefits totaling $9.5 million increased cash flows from financing activities. For the year ended December 31, 2013, changes in excess tax benefits totaling $5.5 million decreased cash flows from financing activities.

Stock Options: Stock options currently outstanding were granted under the NSTAR Incentive Plan, expire ten years from the date of grant and are fully vested. The weighted average remaining contractual lives for the options outstanding as of December 31, 2015 is 2.6 years. 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, 2014</td><td>351,616</td><td>$ 26.69</td><td>$ 9.4</td></tr><tr><td>Exercised</td><td>(179,744)</td><td>$ 26.90</td><td>$ 4.4</td></tr><tr><td>Outstanding and Exercisable - December 31, 2015</td><td>171,872</td><td>$ 26.47</td><td>$ 4.2</td></tr></table>

Cash received for options exercised during the year ended December 31, 2015 totaled $4.8 million. The tax benefit realized from stock options exercised totaled $1.9 million for the year ended December 31, 2015.

Employee Share Purchase Plan: Eversource maintained an ESPP for eligible employees, which allowed for Eversource common shares to be purchased by employees at the end of successive six-month offering periods at 95 percent of the closing market price on the last day of each six-month period. Employees were permitted to purchase shares having a value not exceeding 25 percent of their compensation as of the beginning of the offering period up to a specified limit. The ESPP qualified as a non-compensatory plan under accounting guidance for share-based payments, and no compensation expense was recorded for ESPP purchases.

During 2015, employees purchased 33,715 shares at discounted prices of $52.80 and $47.23. Employees purchased 40,779 shares in 2014 at discounted prices of $41.61 and $41.71. As of December 31, 2015 and 2014, 743,260 and 776,975 shares, respectively, remained available for future issuance under the ESPP. The ESPP ended as of February 1, 2016.

An income tax rate of 40 percent is 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 stock option exercises and fully vested RSUs and performance shares with the issuance of common shares purchased in the open market.

## 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 on the income statements, are as follows:

<table><tr><td rowspan="2"></td><td colspan="4">As of and For the Years Ended December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>Actuarially-Determined Liability</td><td>$ 55.2</td><td>$ 57.5</td><td>$ 51.3</td><td></td></tr><tr><td>Other Retirement Benefits Expense</td><td>3.9</td><td>4.5</td><td>4.4</td><td></td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="6">As of and For the Years Ended December 31,</td></tr><tr><td colspan="2">2015</td><td colspan="2">2014</td><td colspan="2">2013</td></tr><tr><td>(Millions of Dollars)</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>PSNH</td></tr><tr><td>Actuarially-Determined Liability</td><td>$ 0.4</td><td>$ -</td><td>$ 2.4</td><td>$ 0.2</td><td>$ 0.4</td><td>$ -</td></tr><tr><td>Other Retirement Benefits Expense</td><td>1.5</td><td>1.0</td><td>0.7</td><td>0.3</td><td>2.1</td><td>0.3</td></tr></table>



## 10. INCOME TAXES

The components of income tax expense are as follows:

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">For the Years Ended December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>Current Income Taxes:</td><td></td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>$ 6.2</td><td>$ 4.4</td><td>$ 8.8</td><td></td></tr><tr><td>State</td><td>45.7</td><td>24.5</td><td>(9.4)</td><td></td></tr><tr><td>Total Current</td><td>51.9</td><td>28.9</td><td>(0.6)</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>436.1</td><td>406.8</td><td>386.2</td><td></td></tr><tr><td>State</td><td>55.6</td><td>36.5</td><td>45.4</td><td></td></tr><tr><td>Total Deferred</td><td>491.7</td><td>443.3</td><td>431.6</td><td></td></tr><tr><td>Investment Tax Credits, Net</td><td>(3.6)</td><td>(3.9)</td><td>(4.1)</td><td></td></tr><tr><td>Income Tax Expense</td><td>$ 540.0</td><td>$ 468.3</td><td>$ 426.9</td><td></td></tr></table>

For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="4">2015</td><td colspan="4">2014</td><td colspan="4">2013</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>Cl&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td></tr><tr><td>Current Income Taxes:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>$ 26.9</td><td>$ 36.3</td><td>$ (16.7)</td><td>$ (3.5)</td><td>$ (0.2)</td><td>$ 75.0</td><td>$ (22.6)</td><td>$ 1.9</td><td>$ 20.1</td><td>$ 95.8</td><td>$ (8.2)</td><td>$ (53.4)</td></tr><tr><td>State</td><td>15.8</td><td>19.8</td><td>6.0</td><td>1.6</td><td>4.3</td><td>20.2</td><td>(0.1)</td><td>1.8</td><td>(6.7)</td><td>29.6</td><td>3.6</td><td>4.2</td></tr><tr><td>Total Current</td><td>42.7</td><td>56.1</td><td>(10.7)</td><td>(1.9)</td><td>4.1</td><td>95.2</td><td>(22.7)</td><td>3.7</td><td>13.4</td><td>125.4</td><td>(4.6)</td><td>(49.2)</td></tr><tr><td>Deferred Income Taxes, Net:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Federal</td><td>135.8</td><td>147.5</td><td>74.5</td><td>33.4</td><td>138.0</td><td>88.0</td><td>79.6</td><td>28.1</td><td>114.9</td><td>49.8</td><td>64.5</td><td>84.7</td></tr><tr><td>State</td><td>0.2</td><td>25.7</td><td>9.3</td><td>6.0</td><td>(7.1)</td><td>20.1</td><td>15.2</td><td>6.0</td><td>15.1</td><td>(1.0)</td><td>11.2</td><td>2.3</td></tr><tr><td>Total Deferred</td><td>136.0</td><td>173.2</td><td>83.8</td><td>39.4</td><td>130.9</td><td>108.1</td><td>94.8</td><td>34.1</td><td>130.0</td><td>48.8</td><td>75.7</td><td>87.0</td></tr><tr><td>Investment Tax Credits, Net</td><td>(1.3)</td><td>(1.3)</td><td>-</td><td>(0.5)</td><td>(1.5)</td><td>(1.3)</td><td>-</td><td>(0.5)</td><td>$ (1.7)</td><td>(1.3)</td><td>-</td><td>(0.4)</td></tr><tr><td>Income Tax Expense</td><td>$ 177.4</td><td>$ 228.0</td><td>$ 73.1</td><td>$ 37.0</td><td>$ 133.5</td><td>$ 202.0</td><td>$ 72.1</td><td>$ 37.3</td><td>$ 141.7</td><td>$ 172.9</td><td>$ 71.1</td><td>$ 37.4</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>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>Income Before Income Tax Expense</td><td>$ 1,425.9</td><td>$ 1,295.4</td><td>$ 1,220.6</td><td></td></tr><tr><td>Statutory Federal Income Tax Expense at 35%</td><td>499.1</td><td>453.4</td><td>427.2</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>(4.6)</td><td>(5.6)</td><td>(7.4)</td><td></td></tr><tr><td>Investment Tax Credit Amortization</td><td>(3.6)</td><td>(3.9)</td><td>(4.1)</td><td></td></tr><tr><td>Other Federal Tax Credits</td><td>(3.8)</td><td>(3.5)</td><td>(3.7)</td><td></td></tr><tr><td>State Income Taxes, Net of Federal Impact</td><td>61.1</td><td>42.5</td><td>27.6</td><td></td></tr><tr><td>Dividends on ESOP</td><td>(8.1)</td><td>(8.0)</td><td>(8.0)</td><td></td></tr><tr><td>Tax Asset Valuation Allowance/Reserve Adjustments</td><td>4.7</td><td>(2.9)</td><td>(4.3)</td><td></td></tr><tr><td>Other, Net</td><td>(4.8)</td><td>(3.7)</td><td>(0.4)</td><td></td></tr><tr><td>Income Tax Expense</td><td>$ 540.0</td><td>$ 468.3</td><td>$ 426.9</td><td></td></tr><tr><td>Effective Tax Rate</td><td>37.9%</td><td>36.2%</td><td>35.0%</td><td></td></tr></table>



For the Years Ended December 31,

<table><tr><td rowspan="2">(Millions of Dollars, except percentages)</td><td colspan="5">2015</td><td colspan="5">2014</td><td colspan="5">2013</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td></td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WM ECO</td><td></td><td></td></tr><tr><td>Income Before Income Tax Expense</td><td>$ 476.8</td><td>$ 572.6</td><td>$ 187.5</td><td>$ 93.5</td><td>$ 421.2</td><td>$ 505.1</td><td>$ 186.1</td><td>$ 95.1</td><td>$ 421.1</td><td>$ 441.4</td><td>$ 182.5</td><td>$ 97.8</td><td></td><td></td><td></td></tr><tr><td>Statutory Federal Income Tax Expense at 35%</td><td>166.9</td><td>200.4</td><td>65.6</td><td>32.7</td><td>147.4</td><td>176.8</td><td>65.1</td><td>33.3</td><td>147.4</td><td>154.5</td><td>63.9</td><td>34.2</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><td></td><td></td><td></td></tr><tr><td>Depreciation</td><td>(1.7)</td><td>(1.4)</td><td>0.5</td><td>(0.3)</td><td>(3.6)</td><td>(1.3)</td><td>0.3</td><td>(0.2)</td><td>(7.0)</td><td>0.1</td><td>0.6</td><td>-</td><td></td><td></td><td></td></tr><tr><td>Investment Tax Credit Amortization</td><td>(1.3)</td><td>(1.3)</td><td>-</td><td>(0.5)</td><td>(1.5)</td><td>(1.3)</td><td>-</td><td>(0.5)</td><td>(I.7)</td><td>(I.3)</td><td>-</td><td>(0.4)</td><td></td><td></td><td></td></tr><tr><td>Other Federal Tax Credits</td><td>-</td><td>-</td><td>(3.8)</td><td>-</td><td>-</td><td>-</td><td>(3.5)</td><td>-</td><td>-</td><td>-</td><td>(3.7)</td><td>-</td><td></td><td></td><td></td></tr><tr><td>State Income Taxes, Net of Federal Impact</td><td>9.2</td><td>29.6</td><td>9.9</td><td>4.9</td><td>4.4</td><td>26.2</td><td>9.8</td><td>5.0</td><td>5.0</td><td>18.6</td><td>9.6</td><td>4.2</td><td></td><td></td><td></td></tr><tr><td>Tax Asset Valuation Allowance/Reserve Adjustments</td><td>1.2</td><td>-</td><td>-</td><td>-</td><td>(6.3)</td><td>-</td><td>-</td><td>-</td><td>0.4</td><td>-</td><td>-</td><td>-</td><td></td><td></td><td></td></tr><tr><td>Other, Net</td><td>3.1</td><td>0.7</td><td>0.9</td><td>0.2</td><td>(6.9)</td><td>1.6</td><td>0.4</td><td>(0.3)</td><td>(2.4)</td><td>1.0</td><td>0.7</td><td>(0.6)</td><td></td><td></td><td></td></tr><tr><td>Income Tax Expense</td><td>$ 177.4</td><td>$ 228.0</td><td>$ 73.1</td><td>$ 37.0</td><td>$ 133.5</td><td>$ 202.0</td><td>$ 72.1</td><td>$ 37.3</td><td>$ 141.7</td><td>$ 172.9</td><td>$ 71.1</td><td>$ 37.4</td><td></td><td></td><td></td></tr><tr><td>Effective Tax Rate</td><td>37.2%</td><td>39.8%</td><td>39.0%</td><td>39.6%</td><td>31.7%</td><td>40.0%</td><td>38.7%</td><td>39.2%</td><td>33.6%</td><td>39.2%</td><td>39.0%</td><td>38.2%</td><td></td><td></td><td></td></tr></table>

Eversource, CL&P, NSTAR Electric, PSNH and WMECO 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="2">As of December 31,</td></tr><tr><td>2015</td><td>2014</td></tr><tr><td>Deferred Tax Assets:</td><td></td><td></td></tr><tr><td>Employee Benefits</td><td>$ 637.5</td><td>$ 632.2</td></tr><tr><td>Derivative Liabilities</td><td>172.7</td><td>199.6</td></tr><tr><td>Regulatory Deferrals - Liabilities</td><td>243.5</td><td>366.7</td></tr><tr><td>Allowance for Uncollectible Accounts</td><td>60.5</td><td>60.5</td></tr><tr><td>Tax Effect - Tax Regulatory Liabilities</td><td>9.7</td><td>10.0</td></tr><tr><td>Federal Net Operating Loss Carryforwards</td><td>5.4</td><td>59.1</td></tr><tr><td>Purchase Accounting Adjustment</td><td>119.3</td><td>126.2</td></tr><tr><td>Other</td><td>197.1</td><td>198.7</td></tr><tr><td>Total Deferred Tax Assets</td><td>1,445.7</td><td>1,653.0</td></tr><tr><td>Less: Valuation Allowance</td><td>3.7</td><td>5.1</td></tr><tr><td>Net Deferred Tax Assets</td><td>$ 1,442.0</td><td>$ 1,647.9</td></tr><tr><td>Deferred Tax Liabilities:</td><td></td><td></td></tr><tr><td>Accelerated Depreciation and Other Plant-Related Differences</td><td>$ 4,602.6</td><td>$ 4,215.9</td></tr><tr><td>Property Tax Accruals</td><td>76.7</td><td>109.6</td></tr><tr><td>Regulatory Amounts:</td><td></td><td></td></tr><tr><td>Regulatory Deferrals - Assets</td><td>1,289.1</td><td>1,277.9</td></tr><tr><td>Tax Effect - Tax Regulatory Assets</td><td>249.3</td><td>240.2</td></tr><tr><td>Goodwill Regulatory Asset - 1999 Merger</td><td>194.9</td><td>203.2</td></tr><tr><td>Derivative Assets</td><td>17.7</td><td>32.6</td></tr><tr><td>Other</td><td>159.4</td><td>196.3</td></tr><tr><td>Total Deferred Tax Liabilities</td><td>$ 6,589.7</td><td>$ 6,275.7</td></tr></table>



<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="12">As of December 31,</td></tr><tr><td colspan="3">NSTAR Electric</td><td colspan="3">2015</td><td colspan="3">2014</td><td colspan="3">2014</td></tr><tr><td>Deferred Tax Assets:</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</td><td></td><td></td><td></td><td></td></tr><tr><td>Employee Benefits</td><td>$ 126.1</td><td>$ 91.3</td><td>$ 37.1</td><td>$ 10.0</td><td>$ 129.0</td><td>$ 39.9</td><td>$ 46.8</td><td>$ 9.2</td><td></td><td></td><td></td><td></td></tr><tr><td>Derivative Liabilities</td><td>165.7</td><td>0.6</td><td>-</td><td>-</td><td>193.0</td><td>1.8</td><td>-</td><td>-</td><td></td><td></td><td></td><td></td></tr><tr><td>Regulatory Deferrals - Liabilities</td><td>36.0</td><td>109.4</td><td>42.1</td><td>6.1</td><td>73.9</td><td>181.3</td><td>46.5</td><td>11.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Allowance for Uncollectible Accounts</td><td>30.4</td><td>8.5</td><td>3.6</td><td>4.5</td><td>32.3</td><td>13.8</td><td>3.2</td><td>3.8</td><td></td><td></td><td></td><td></td></tr><tr><td>Tax Effect - Tax Regulatory Liabilities</td><td>3.1</td><td>1.5</td><td>2.3</td><td>2.4</td><td>3.1</td><td>1.8</td><td>2.1</td><td>2.5</td><td></td><td></td><td></td><td></td></tr><tr><td>Federal Net Operating Loss Carryforwards</td><td>-</td><td>-</td><td>2.4</td><td>0.4</td><td>-</td><td>-</td><td>32.1</td><td>4.5</td><td></td><td></td><td></td><td></td></tr><tr><td>Other</td><td>55.5</td><td>3.4</td><td>61.1</td><td>5.0</td><td>53.8</td><td>19.9</td><td>48.9</td><td>4.9</td><td></td><td></td><td></td><td></td></tr><tr><td>Total Deferred Tax Assets</td><td>416.8</td><td>214.7</td><td>148.6</td><td>28.4</td><td>485.1</td><td>258.5</td><td>179.6</td><td>36.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Less: Valuation Allowance</td><td>3.1</td><td>-</td><td>-</td><td>-</td><td>4.0</td><td>-</td><td>-</td><td>-</td><td></td><td></td><td></td><td></td></tr><tr><td>Net Deferred Tax Assets</td><td>$ 413.7</td><td>$ 214.7</td><td>$ 148.6</td><td>$ 28.4</td><td>$ 481.1</td><td>$ 258.5</td><td>$ 179.6</td><td>$ 36.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Deferred Tax Liabilities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Accelerated Depreciation and Other</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>Plant-Related Differences</td><td>$ 1,545.6</td><td>$ 1,387.1</td><td>$ 655.3</td><td>$ 416.1</td><td>$ 1,378.6</td><td>$ 1,296.9</td><td>$ 596.6</td><td>$ 385.8</td><td></td><td></td><td></td><td></td></tr><tr><td>Property Tax Accruals</td><td>27.3</td><td>22.8</td><td>7.3</td><td>10.6</td><td>58.1</td><td>25.0</td><td>7.4</td><td>12.8</td><td></td><td></td><td></td><td></td></tr><tr><td>Regulatory Amounts:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Regulatory Deferrals - Assets</td><td>456.8</td><td>339.7</td><td>137.9</td><td>60.5</td><td>502.3</td><td>276.0</td><td>147.6</td><td>60.4</td><td></td><td></td><td></td><td></td></tr><tr><td>Tax Effect - Tax Regulatory Assets</td><td>168.7</td><td>36.0</td><td>15.4</td><td>9.0</td><td>166.9</td><td>35.5</td><td>15.9</td><td>9.3</td><td></td><td></td><td></td><td></td></tr><tr><td>Goodwill Regulatory Asset - 1999 Merger</td><td>-</td><td>167.4</td><td>-</td><td>-</td><td>-</td><td>174.4</td><td>-</td><td>-</td><td></td><td></td><td></td><td></td></tr><tr><td>Derivative Assets</td><td>17.7</td><td>-</td><td>-</td><td>-</td><td>32.6</td><td>-</td><td>-</td><td>-</td><td></td><td></td><td></td><td></td></tr><tr><td>Other</td><td>18.5</td><td>22.0</td><td>38.6</td><td>2.7</td><td>19.4</td><td>33.5</td><td>35.6</td><td>2.8</td><td></td><td></td><td></td><td></td></tr><tr><td>Total Deferred Tax Liabilities</td><td>$ 2,234.6</td><td>$ 1,975.0</td><td>$ 854.5</td><td>$ 498.9</td><td>$ 2,157.9</td><td>$ 1,841.3</td><td>$ 803.1</td><td>$ 471.1</td><td></td><td></td><td></td><td></td></tr></table>

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="8">As of December 31, 2015</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</td><td>Expiration Range</td><td></td><td></td></tr><tr><td>Federal Net Operating Loss</td><td>$ 15.5</td><td>$ -</td><td>$ -</td><td>$ 7.0</td><td>$ 1.0</td><td>2032</td><td></td><td></td></tr><tr><td>Federal Tax Credit</td><td>26.1</td><td>0.1</td><td>0.2</td><td>15.0</td><td>-</td><td>2031 - 2035</td><td></td><td></td></tr><tr><td>Federal Charitable Contribution</td><td>14.9</td><td>-</td><td>-</td><td>-</td><td>-</td><td>2016 - 2018</td><td></td><td></td></tr><tr><td>State Tax Credit</td><td>101.2</td><td>73.8</td><td>-</td><td>-</td><td>-</td><td>2015 - 2020</td><td></td><td></td></tr><tr><td>State Charitable Contribution</td><td>3.0</td><td>-</td><td>-</td><td>-</td><td>-</td><td>2015 - 2019</td><td></td><td></td></tr></table>

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="8">As of December 31, 2014</td></tr><tr><td>Eversource</td><td>CL&amp;P</td><td>Electric</td><td>PSNH</td><td>WMECO</td><td>Expiration Range</td><td></td><td></td></tr><tr><td>Federal Net Operating Loss</td><td>$ 168.8</td><td>$ -</td><td>$ -</td><td>$ 91.8</td><td>$ 12.7</td><td>2031 - 2032</td><td></td><td></td></tr><tr><td>Federal Tax Credit</td><td>16.3</td><td>0.1</td><td>0.2</td><td>11.1</td><td>-</td><td>2031 - 2034</td><td></td><td></td></tr><tr><td>Federal Charitable Contribution</td><td>19.4</td><td>-</td><td>-</td><td>-</td><td>-</td><td>2016 - 2018</td><td></td><td></td></tr><tr><td>State Tax Credit</td><td>99.7</td><td>71.0</td><td>-</td><td>-</td><td>-</td><td>2014 - 2019</td><td></td><td></td></tr><tr><td>State Loss Carryforwards</td><td>40.6</td><td>-</td><td>-</td><td>-</td><td>-</td><td>2014 - 2034</td><td></td><td></td></tr><tr><td>State Charitable Contribution</td><td>2.1</td><td>-</td><td>-</td><td>-</td><td>-</td><td>2015 - 2018</td><td></td><td></td></tr></table>

In 2015, the Company decreased its valuation allowance reserve for state credits and state loss carryforwards by $1.3 million (CL&P $0.9 million), net of tax, to reflect an update for expired state tax credits and loss carryforwards.

In 2014, the Company recorded a reduction to its state credit carryforwards of $11 million (CL&P $10.1 million), net of tax, as a result of an update to reflect the amounts expired. Further, the Company decreased its valuation allowance reserve for state credits by $19.2 million at CL&P, net of tax, to reflect an update for expired state credits and latest estimate of usage.

For 2015 and 2014, state credit and state loss carryforwards have been partially reserved by a valuation allowance of $3.1 million and $4.4 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, 2013</td><td>$ 83.1</td><td>$ 49.0</td></tr><tr><td>Gross Increases - Current Year</td><td>8.2</td><td>2.1</td></tr><tr><td>Gross Decreases - Prior Year</td><td>(1.1)</td><td>(0.3)</td></tr><tr><td>Settlements</td><td>(49.8)</td><td>(39.4)</td></tr><tr><td>Lapse of Statute of Limitations</td><td>(2.2)</td><td>-</td></tr><tr><td>Balance as of December 31, 2013</td><td>38.2</td><td>11.4</td></tr><tr><td>Gross Increases - Current Year</td><td>9.3</td><td>2.7</td></tr><tr><td>Gross Increases - Prior Year</td><td>0.3</td><td>0.2</td></tr><tr><td>Lapse of Statute of Limitations</td><td>(1.6)</td><td>-</td></tr><tr><td>Balance as of December 31, 2014</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></table>

Interest and Penalties: Interest on uncertain tax positions is recorded and generally classified as a component of Other Interest Expense on the statements of income. However, when resolution of uncertainties results in the Company receiving interest income, any related interest benefit is recorded in Other Income, Net on the statements of income. No penalties have been recorded. The amount of interest expense/(income) on uncertain tax positions recognized and the related accrued interest payable/(receivable) are as follows:

<table><tr><td rowspan="3">(Millions of Dollars)</td><td colspan="4">Other Interest Expense/(Income)</td><td colspan="4">Accrued Interest Expense</td></tr><tr><td colspan="4">For the Years Ended December 31,</td><td colspan="4">As of December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td><td></td><td>2015</td><td>2014</td><td></td><td></td></tr><tr><td>Eversource</td><td>$ 0.1</td><td>$ 0.4</td><td>$ (8.6)</td><td>$ 2.0</td><td>$ 1.9</td><td></td><td></td><td></td></tr><tr><td>CL&amp;P</td><td>-</td><td>-</td><td>(4.0)</td><td>-</td><td>-</td><td></td><td></td><td></td></tr></table>

Tax Positions: During 2015 and 2014, Eversource did not resolve any of its uncertain tax positions.

Open Tax Years: The following table summarizes Eversource, CL&P, NSTAR Electric, PSNH and WMECO’s tax years that remain subject to examination by major tax jurisdictions as of December 31, 2015:

<table><tr><td>Description</td><td>Tax Years</td></tr><tr><td>Federal</td><td>2015</td></tr><tr><td>Connecticut</td><td>2012 - 2015</td></tr><tr><td>Massachusetts</td><td>2012 - 2015</td></tr><tr><td>New Hampshire</td><td>2012 - 2015</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 $2.3 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.

2015 Federal Legislation: On December 18, 2015, the “Protecting Americans from Tax Hikes” Act became law, which extended the accelerated deduction of depreciation to businesses from 2015 through 2019. This extended stimulus provides Eversource with cash flow benefits in 2016 of approximately $275 million (including approximately $105 million for CL&P, $72 million for NSTAR Electric, $46 million for PSNH, and $25 million for WMECO) due to a refund of taxes paid in 2015 and lower expected tax payments in 2016 of approximately $300 million.

2015 Connecticut Legislation: In 2015, the state of Connecticut enacted several changes to its corporate tax laws. Among the changes, commencing as of January 1, 2015, is the reduction in the amount of tax credits that corporations can utilize against its tax liability in a year and a continuation of the corporate income tax surcharge through 2018, which effectively increases the state corporate tax rate to 9 percent for the years 2016 and 2017 and 8.25 percent for 2018. Also, effective January 1, 2016, all Connecticut companies have a mandatory unitary tax filing requirement. Management continues to review the tax law changes and their impact on the effective tax rates of Eversource and CL&P.

2014 Federal Legislation: On December 19, 2014, the “Tax Increase Prevention Act of 2014” became law, which extended the accelerated deduction of depreciation to businesses through 2014. This extended stimulus provided Eversource with cash flow benefits of approximately $250 million (approximately $86 million at CL&P, $64 million at NSTAR Electric, $44 million at PSNH, and $21 million at WMECO) in 2015.

## 11. COMMITMENTS AND CONTINGENCIES

## A. Environmental Matters

General: Eversource, CL&P, NSTAR Electric, PSNH and WMECO 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, PSNH and WMECO have an active environmental auditing and training program and believe that they are 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 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, CL&P, NSTAR Electric, PSNH and WMECO'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 included in Other Current Liabilities and Other Long-Term Liabilities on the balance sheets 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 previously 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><td>WMECO</td></tr><tr><td>Balance as of January 1, 2014</td><td>$     35.4</td><td>$     3.4</td><td>$     1.2</td><td>$     5.4</td><td>$     0.4</td></tr><tr><td>Additions</td><td>12.7</td><td>1.0</td><td>-</td><td>0.1</td><td>0.2</td></tr><tr><td>Payments/Reductions</td><td>(4.8)</td><td>(0.6)</td><td>(0.1)</td><td>(0.3)</td><td>(0.1)</td></tr><tr><td>Balance as of December 31, 2014</td><td>43.3</td><td>3.8</td><td>1.1</td><td>5.2</td><td>0.5</td></tr><tr><td>Additions</td><td>13.5</td><td>1.3</td><td>2.0</td><td>2.3</td><td>0.2</td></tr><tr><td>Payments/Reductions</td><td>(5.7)</td><td>(0.5)</td><td>(0.7)</td><td>(3.0)</td><td>(0.1)</td></tr><tr><td>Balance as of December 31, 2015</td><td>$     51.1</td><td>$     4.6</td><td>$     2.4</td><td>$     4.5</td><td>$     0.6</td></tr></table>

The number of related environmental sites and 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="2">As of December 31, 2015</td><td colspan="2">As of December 31, 2014</td></tr><tr><td>Number of Sites</td><td>Reserve (in millions)</td><td>Number of Sites</td><td>Reserve (in millions)</td></tr><tr><td>Eversource</td><td>64</td><td>51.1</td><td>65</td><td>43.3</td></tr><tr><td>CL&amp;P</td><td>14</td><td>4.6</td><td>16</td><td>3.8</td></tr><tr><td>NSTAR Electric</td><td>15</td><td>2.4</td><td>13</td><td>1.1</td></tr><tr><td>PSNH</td><td>12</td><td>4.5</td><td>13</td><td>5.2</td></tr><tr><td>WMECO</td><td>4</td><td>0.6</td><td>4</td><td>0.5</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 $45.5 million and $38.8 million as of December 31, 2015 and 2014, respectively, and related primarily to the natural gas business segment.

As of December 31, 2015, for 9 environmental sites (3 for CL&P, 1 for WMECO) 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, 2015, $24.7 million (including $1.7 million for CL&P and $0.3 million for WMECO) 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 $33.9 million (approximately $1.4 million for CL&P, and $0.1 million for WMECO) may be incurred in remediating these sites.

As of December 31, 2015, for 12 environmental sites (3 for CL&P and 2 for NSTAR Electric) that are included in the Company’s reserve for environmental costs, management cannot reasonably estimate the exposure to loss in excess of the reserve, or range of loss, as these sites are under investigation and/or there is significant uncertainty as to what remedial actions, if any, the Company may be required to undertake. As of December 31, 2015, $13.7 million (including $2 million for CL&P) had been accrued as a liability for these sites. As of December 31, 2015, for the remaining 43 environmental sites (including 8 for CL&P, 13 for NSTAR Electric, 12 for PSNH, and 3 for WMECO) that are included in the Company’s reserve for environmental costs, the $12.7 million accrual (including $0.9 million for CL&P, $2.4 million for NSTAR Electric, $4.5 million for PSNH, and $0.3 million for WMECO) represents management’s best estimate of the potential 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, 2015, a liability of $0.8 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, NSTAR Electric and WMECO 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, 2015 are as follows:

<table><tr><td>Eversource</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>(Millions of Dollars)</td><td>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>Thereafter</td><td>Total</td><td></td></tr><tr><td>Supply and Stranded Cost</td><td>$ 177.4</td><td>$ 110.1</td><td>$ 81.5</td><td>$ 51.1</td><td>$ 34.9</td><td>$ 80.6</td><td>$ 535.6</td><td></td></tr><tr><td>Renewable Energy</td><td>246.6</td><td>273.3</td><td>238.3</td><td>237.4</td><td>237.0</td><td>2,174.7</td><td>3,407.3</td><td></td></tr><tr><td>Peaker CfDs</td><td>55.8</td><td>41.1</td><td>20.4</td><td>7.8</td><td>4.0</td><td>3.6</td><td>132.7</td><td></td></tr><tr><td>Natural Gas Procurement</td><td>137.9</td><td>123.8</td><td>78.4</td><td>57.8</td><td>46.9</td><td>99.7</td><td>544.5</td><td></td></tr><tr><td>Coal, Wood and Other</td><td>45.4</td><td>23.3</td><td>3.4</td><td>1.9</td><td>1.9</td><td>13.1</td><td>89.0</td><td></td></tr><tr><td>Transmission Support Commitments</td><td>21.4</td><td>19.0</td><td>20.3</td><td>20.2</td><td>20.2</td><td>-</td><td>101.1</td><td></td></tr><tr><td>Total</td><td>$ 684.5</td><td>$ 590.6</td><td>$ 442.3</td><td>$ 376.2</td><td>$ 344.9</td><td>$ 2,371.7</td><td>$ 4,810.2</td><td></td></tr></table>

<table><tr><td>CL&amp;P</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>(Millions of Dollars)</td><td>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>Thereafter</td><td>Total</td><td></td></tr><tr><td>Supply and Stranded Cost</td><td>$ 145.0</td><td>$ 87.2</td><td>$ 58.2</td><td>$ 38.0</td><td>$ 29.3</td><td>$ 47.6</td><td>$ 405.3</td><td></td></tr><tr><td>Renewable Energy</td><td>70.1</td><td>71.7</td><td>72.1</td><td>72.3</td><td>72.4</td><td>649.7</td><td>1,008.3</td><td></td></tr><tr><td>Peaker CfDs</td><td>55.8</td><td>41.1</td><td>20.4</td><td>7.8</td><td>4.0</td><td>3.6</td><td>132.7</td><td></td></tr><tr><td>Transmission Support Commitments</td><td>8.4</td><td>7.5</td><td>8.0</td><td>8.0</td><td>8.0</td><td>-</td><td>39.9</td><td></td></tr><tr><td>Yankee Companies Billings</td><td>0.1</td><td>0.4</td><td>0.8</td><td>0.8</td><td>0.8</td><td>10.7</td><td>13.6</td><td></td></tr><tr><td>Total</td><td>$ 279.4</td><td>$ 207.9</td><td>$ 159.5</td><td>$ 126.9</td><td>$ 114.5</td><td>$ 711.6</td><td>$ 1,599.8</td><td></td></tr></table>

<table><tr><td>(Millions of Dollars)</td><td>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>Thereafter</td><td>Total</td></tr><tr><td>Supply and Stranded Cost</td><td>$ 14.1</td><td>$ 4.8</td><td>$ 5.5</td><td>$ 5.5</td><td>$ 3.1</td><td>$ 28.1</td><td>$ 61.1</td></tr><tr><td>Renewable Energy</td><td>99.0</td><td>117.0</td><td>80.4</td><td>78.5</td><td>76.6</td><td>489.8</td><td>941.3</td></tr><tr><td>Transmission Support Commitments</td><td>6.6</td><td>5.9</td><td>6.3</td><td>6.2</td><td>6.2</td><td>-</td><td>31.2</td></tr><tr><td>Yankee Companies Billings</td><td>0.1</td><td>0.2</td><td>0.3</td><td>0.3</td><td>0.3</td><td>3.6</td><td>4.8</td></tr><tr><td>Total</td><td>$ 119.8</td><td>$ 127.9</td><td>$ 92.5</td><td>$ 90.5</td><td>$ 86.2</td><td>$ 521.5</td><td>$ 1,038.4</td></tr></table>

<table><tr><td>(PSNH)</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>(Millions of Dollars)</td><td>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>Thereafter</td><td>Total</td><td></td></tr><tr><td>Supply and Stranded Cost</td><td>$ 18.3</td><td>$ 18.1</td><td>$ 17.8</td><td>$ 7.6</td><td>$ 2.5</td><td>$ 4.9</td><td>$ 69.2</td><td></td></tr><tr><td>Renewable Energy</td><td>67.9</td><td>69.0</td><td>70.1</td><td>70.7</td><td>72.0</td><td>860.4</td><td>1,210.1</td><td></td></tr><tr><td>Coal, Wood and Other</td><td>45.4</td><td>23.3</td><td>3.4</td><td>1.9</td><td>1.9</td><td>13.1</td><td>89.0</td><td></td></tr><tr><td>Transmission Support Commitments</td><td>4.6</td><td>4.0</td><td>4.3</td><td>4.3</td><td>4.3</td><td>-</td><td>21.5</td><td></td></tr><tr><td>Yankee Companies Billings</td><td>0.1</td><td>0.2</td><td>0.3</td><td>0.3</td><td>0.3</td><td>4.2</td><td>5.4</td><td></td></tr><tr><td>Total</td><td>$ 136.3</td><td>$ 114.6</td><td>$ 95.9</td><td>$ 84.8</td><td>$ 81.0</td><td>$ 882.6</td><td>$ 1,395.2</td><td></td></tr></table>

<table><tr><td>WMECO</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>(Millions of Dollars)</td><td>2016</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>Thereafter</td><td>Total</td><td></td></tr><tr><td>Renewable Energy</td><td>$ 9.6</td><td>$ 15.6</td><td>$ 15.7</td><td>$ 15.9</td><td>$ 16.0</td><td>$ 174.8</td><td>$ 247.6</td><td></td></tr><tr><td>Transmission Support Commitments</td><td>1.8</td><td>1.6</td><td>1.7</td><td>1.7</td><td>1.7</td><td>-</td><td>8.5</td><td></td></tr><tr><td>Yankee Companies Billings</td><td>-</td><td>0.1</td><td>0.2</td><td>0.2</td><td>0.2</td><td>2.7</td><td>3.4</td><td></td></tr><tr><td>Total</td><td>$ 11.4</td><td>$ 17.3</td><td>$ 17.6</td><td>$ 17.8</td><td>$ 17.9</td><td>$ 177.5</td><td>$ 259.5</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 projects 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 will share 20 percent of the costs and benefits of these contracts. CL&P’s portion of the costs and benefits of these contracts will be paid by or refunded to CL&P’s customers.

The contractual obligations table above does not include CL&P’s, NSTAR Electric’s or WMECO’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, PSNH, and WMECO for the purchase of energy and capacity from renewable energy facilities. Such contracts extend through 2035 for CL&P, 2031 for NSTAR Electric, 2033 for PSNH and 2031 for WMECO.

The contractual obligations table above does not include long-term commitments signed by CL&P, NSTAR Electric and WMECO, 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 2029.

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. Also included in the contractual obligations table above is a contract for capacity on the Portland Natural Gas Transmission System (PNGTS) pipeline that extends through 2018. The costs of this contract of $4.5 million are not recoverable from customers.

Transmission Support Commitments: Along with other New England utilities, CL&P, NSTAR Electric, PSNH and WMECO 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, PSNH and WMECO 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.

Yankee Companies Billings: CL&P, NSTAR Electric, PSNH and WMECO have decommissioning and plant closure 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. For further information on the Yankee Companies, see Note 11C, “Commitments and Contingencies - Contractual Obligations - Yankee Companies,” to the financial statements.

The total costs incurred under these agreements were as follows:

<table><tr><td rowspan="2">Eversource (Millions of Dollars)</td><td colspan="5">For the Years Ended December 31,</td></tr><tr><td>2015</td><td>2014</td><td>2013</td><td></td><td></td></tr><tr><td>Supply and Stranded Cost</td><td>$ 147.6</td><td>$ 99.2</td><td>$ 141.0</td><td></td><td></td></tr><tr><td>Renewable Energy</td><td>144.3</td><td>114.4</td><td>91.3</td><td></td><td></td></tr><tr><td>Peaker CfDs</td><td>42.7</td><td>18.1</td><td>51.9</td><td></td><td></td></tr><tr><td>Natural Gas Procurement</td><td>428.6</td><td>482.5</td><td>349.8</td><td></td><td></td></tr><tr><td>Coal, Wood and Other</td><td>95.9</td><td>120.5</td><td>112.6</td><td></td><td></td></tr><tr><td>Transmission Support Commitments</td><td>25.3</td><td>25.0</td><td>24.9</td><td></td><td></td></tr></table>

<table><tr><td rowspan="2">(Millions of Dollars)</td><td colspan="5">2015</td><td colspan="5">2014</td><td colspan="5">2013</td></tr><tr><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>CL&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td>Cl&amp;P</td><td>NSTAR Electric</td><td>PSNH</td><td>WMECO</td><td></td><td></td></tr><tr><td>Supply and Stranded Cost</td><td>$ 120.3</td><td>$ 6.5</td><td>$ 20.8</td><td>$ -</td><td>$ 63.0</td><td>$ 7.0</td><td>$ 26.0</td><td>$ 3.2</td><td>$ 77.6</td><td>$ 32.4</td><td>$ 29.0</td><td>$ 2.0</td><td></td><td></td></tr><tr><td>Renewable Energy</td><td>20.0</td><td>86.7</td><td>37.2</td><td>0.4</td><td>0.7</td><td>87.4</td><td>26.3</td><td>-</td><td>-</td><td>84.9</td><td>6.4</td><td>-</td><td></td><td></td></tr><tr><td>Peaker CfDs</td><td>42.7</td><td>-</td><td>-</td><td>-</td><td>18.1</td><td>-</td><td>-</td><td>-</td><td>51.9</td><td>-</td><td>-</td><td>-</td><td></td><td></td></tr><tr><td>Coal, Wood and Other</td><td>-</td><td>-</td><td>95.9</td><td>-</td><td>-</td><td>-</td><td>120.5</td><td>-</td><td>-</td><td>-</td><td>112.6</td><td>-</td><td></td><td></td></tr><tr><td>Transmission Support Commitments</td><td>10.0</td><td>7.8</td><td>5.4</td><td>2.1</td><td>9.9</td><td>7.7</td><td>5.3</td><td>2.1</td><td>9.8</td><td>7.7</td><td>5.3</td><td>2.1</td><td></td><td></td></tr></table>

## C. Contractual Obligations - Yankee Companies

CL&P, NSTAR Electric, PSNH and WMECO 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, PSNH and WMECO. 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, NSTAR Electric and WMECO will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers.

CL&P, NSTAR Electric, PSNH and WMECO’s percentage share of the obligations to support the Yankee Companies under FERC-approved rate tariffs is the same as their respective ownership percentages in the Yankee Companies. For further information on the ownership percentages, see Note 1J, “Summary of Significant Accounting Policies - Equity Method Investments,” to the financial statements.



DOE Phase I Damages – In 2013, CYAPC, YAEC and MYAPC received proceeds of $39.6 million, $38.3 million, and $81.7 million, respectively, based on a final court judgment awarding damages for separate complaints filed by the Yankee Companies in 1998 against the DOE seeking monetary damages resulting from the DOE’s failure to begin accepting spent nuclear fuel for disposal 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 period 1998 through 2002. In 2013, CYAPC, YAEC and MYAPC reduced rates in their wholesale power contracts through the application of the DOE proceeds for the benefit of customers. CL&P, NSTAR Electric, PSNH and WMECO began receiving the benefit of the Phase I DOE proceeds in 2013, and the benefits are being passed on to customers.

In accordance with MYAPC’s three-year refund plan of the DOE Phase I Damages proceeds, in September 2014, MYAPC returned the second portion of the proceeds to the member companies, including CL&P, NSTAR Electric, PSNH, and WMECO, in the amount of $3.2 million, $1.1 million, $1.4 million and $0.8 million, respectively. On September 28, 2015, MYAPC returned the remaining DOE Phase I Damages proceeds to the member companies, including CL&P, NSTAR Electric, PSNH, and WMECO, in the amount of $2.3 million, $0.8 million, $1 million and $0.6 million, respectively. These amounts reduced receivables at CL&P, NSTAR Electric, PSNH and WMECO.

DOE Phase II Damages - In 2014, CYAPC, YAEC and MYAPC received proceeds of $126.3 million, $73.3 million and $35.8 million, respectively, based on a final court judgment awarding damages for separate lawsuits filed by the Yankee Companies in 2007 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). The Yankee Companies returned the DOE Phase II Damages proceeds to the member companies, including CL&P, NSTAR Electric, PSNH, and WMECO, for the benefit of their respective customers in June 2014.

As of December 31, 2014, CL&P’s refund obligation to customers of $65.4 million was recorded as an offset to the deferred storm restoration costs regulatory asset, as directed by PURA. NSTAR Electric’s, PSNH’s and WMECO’s refund obligation to customers of $29.1 million, $13.1 million and $18.1 million, respectively, was recorded as a regulatory liability in each company’s respective regulatory tracker mechanisms. Refunds to customers for these Phase II DOE proceeds were completed in 2015.

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. The DOE Phase III trial concluded on July 1, 2015, with a post-trial briefing that concluded on October 14, 2015. The parties are awaiting a decision from the court.

## 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, PSNH and WMECO, in the form of guarantees.

Eversource parent issued a declining balance guaranty on behalf of a wholly-owned subsidiary to guarantee the payment of the subsidiary’s capital contributions for its investment in the Access Northeast project. The guarantee will not exceed $206 million and will decrease as capital contributions are made. The guaranty will expire upon the earlier of the full performance of the guaranteed obligations or December 31, 2021.

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 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 as a result of these various guarantees and indemnifications.

The following table summarizes Eversource parent’s exposure to guarantees and indemnifications of its subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, and guarantees to external parties, as of December 31, 2015:

<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>Various</td><td>Surety Bonds \( ^{(1)} \)</td><td>32.7</td><td>2016 - 2018</td></tr><tr><td>Eversource Service and Rocky River Realty Company</td><td>Lease Payments for Vehicles and Real Estate</td><td>11.4</td><td>2019 and 2024</td></tr><tr><td>On behalf of external parties:</td><td></td><td></td><td></td></tr><tr><td>Algonquin Gas Transmission, LLC (owner of Access Northeast assets)</td><td>Access Northeast project capital contributions guarantee</td><td>204.8</td><td>2021</td></tr></table>

(1) Surety bond expiration dates reflect termination dates, the majority of which will be renewed or extended. Certain surety bonds contain credit ratings triggers that would require Eversource parent to post collateral in the event that the unsecured debt credit ratings of Eversource are downgraded.



## E. FERC ROE Complaints

Three separate complaints have been filed at FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (the "Complainants"). In the first complaint, filed in 2011, the Complainants alleged that the NETOs' base ROE that had been utilized since 2006 was unjust and unreasonable, asserted that the rate was excessive due to changes in the capital markets, and sought an order to reduce it prospectively from the date of the final FERC order and for the 15-month period beginning October 1, 2011 to December 31, 2012. In the second and third complaints, filed in 2012 and 2014, the Complainants challenged the NETOs' base ROE and sought refunds for the respective 15-month periods beginning December 27, 2012 and July 31, 2014.

As a result of the actions taken by the FERC and other developments in the first complaint matter, the Company recorded additional reserves at its electric subsidiaries in 2015 and 2014. In 2015, Eversource recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO. The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues. In 2014, the net aggregate pre-tax charge to earnings (excluding interest) totaled $37 million, of which $20.7 million was recorded at CL&P, $7.9 million at NSTAR Electric, $2.8 million at PSNH and $5.6 million at WMECO. In 2013, the net aggregate pre-tax charge to earnings (excluding interest) totaled $23.7 million, of which $12.8 million was recorded at CL&P, $5.7 million at NSTAR Electric, $2.3 million at PSNH and $2.9 million at WMECO.

The second and third complaint proceedings are ongoing and a final FERC order is expected in late 2016 or early 2017. Although management is uncertain on the final outcome of the second and third complaints regarding the ROE, management believes the current reserves established are appropriate to reflect probable and reasonably estimable refunds.

## F. NSTAR Electric and NSTAR Gas Comprehensive Settlement Agreement

On March 2, 2015, the DPU approved the comprehensive settlement agreement between NSTAR Electric, NSTAR Gas and the Massachusetts Attorney General (the "Settlement") as filed with the DPU on December 31, 2014. The Settlement resolved the outstanding NSTAR Electric CPSL program filings for 2006 through 2011, the NSTAR Electric and NSTAR Gas PAM and energy efficiency-related customer billing adjustments reported in 2012, and the recovery of LBR related to NSTAR Electric's energy efficiency programs for 2009 through 2011 (11 dockets in total). In the first quarter of 2015, as a result of the DPU order, NSTAR Electric and NSTAR Gas commenced refunding a combined $44.7 million to customers, which was recorded as a regulatory liability. Refunds to customers will continue through December 2016. As a result of the Settlement, NSTAR Electric increased its operating revenues and decreased its amortization expense in 2015, resulting in the recognition of a $21.7 million pretax benefit in 2015.

## G. NSTAR Electric Basic Service Bad Debt Adder

On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006. As a result of the DPU order, in the first quarter of 2015, NSTAR Electric increased its regulatory assets and reduced its operations and maintenance expense by an under recovered amount of $24.2 million for energy-related bad debt costs through 2014, resulting in a pre-tax benefit in 2015. NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers and on November 20, 2015 the DPU approved NSTAR Electric’s proposed rate increase, to recover these costs over a 12-month period, effective January 1, 2016.

## H. PSNH Generation Restructuring

On June 10, 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement (the Agreement) with the New Hampshire Office of Energy and Planning, certain members of the NHPUC staff, the Office of Consumer Advocate, two State Senators, and several other parties. The Agreement was filed with the NHPUC on the same day. Under the terms of the Agreement, PSNH has agreed to divest its generation assets upon NHPUC approval. The Agreement is designed to provide a resolution of issues pertaining to PSNH's generation assets in pending regulatory proceedings before the NHPUC. The Agreement provided for the Clean Air Project prudence proceeding to be resolved and all remaining Clean Air Project costs to be included in rates effective January 1, 2016. As part of the Agreement, PSNH has agreed to forego recovery of $25 million of the deferred equity return related to the Clean Air Project. In addition, PSNH will not seek a general distribution rate increase effective before July 1, 2017 and will contribute $5 million to create a clean energy fund, which will not be recoverable from its customers. In 2015, PSNH recorded the $5 million contribution as a long-term liability and an increase to Operations and Maintenance expense on the statements of income.

Upon completion of the divestiture process, all remaining stranded costs will be recovered via bonds that will be secured by a non-bypassable charge or through other recoveries in rates billed to PSNH customers.

On January 26, 2016, Advisory Staff of the NHPUC and the parties to the Agreement filed a stipulation with the NHPUC agreeing that near-term divestiture of PSNH’s generation was in the public interest and that the Agreement should be approved. Implementation of the Agreement is subject to NHPUC approval, which is expected in early 2016.

If the NHPUC approves the settlements and the sale of the plants, then management expects to sell the plants in the first half of 2017. The sales price of the generating assets could be less than the carrying value, but we believe that full recovery of PSNH’s generation assets is probable through a combination of cash flows during the remaining operating period, sales proceeds upon divestiture, and recovery of stranded costs in future rates.



## I. Litigation and Legal Proceedings

Eversource, including CL&P, NSTAR Electric, PSNH and WMECO, 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. LEASES

Eversource, including CL&P, NSTAR Electric, PSNH and WMECO, has entered into lease agreements, some of which are capital leases, for the use of data processing and office equipment, vehicles, service centers, and office space. In addition, CL&P, NSTAR Electric, PSNH and WMECO incur costs associated with leases entered into by Eversource Service and Rocky River Realty Company, which 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, PSNH, and WMECO 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><td>WMECO</td></tr><tr><td>2015</td><td>$ 12.1</td><td>$ 12.5</td><td>$ 9.6</td><td>$ 2.8</td><td>$ 2.2</td></tr><tr><td>2014</td><td>14.3</td><td>6.0</td><td>7.8</td><td>1.5</td><td>1.2</td></tr><tr><td>2013</td><td>16.3</td><td>8.1</td><td>6.7</td><td>1.7</td><td>2.9</td></tr></table>

The 2015 rental payments above for CL&P, NSTAR Electric, PSNH, and WMECO include an intercompany rate of return, property tax and operational expense component paid to Rocky River Realty Company.

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, 2015 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><td>WMECO</td></tr><tr><td>2016</td><td>$ 16.4</td><td>$ 2.9</td><td>$ 9.7</td><td>$ 0.8</td><td>$ 0.8</td></tr><tr><td>2017</td><td>13.8</td><td>2.0</td><td>8.5</td><td>0.7</td><td>0.7</td></tr><tr><td>2018</td><td>10.4</td><td>1.3</td><td>6.5</td><td>0.5</td><td>0.6</td></tr><tr><td>2019</td><td>8.5</td><td>1.0</td><td>5.3</td><td>0.4</td><td>0.5</td></tr><tr><td>2020</td><td>6.8</td><td>0.7</td><td>4.3</td><td>0.3</td><td>0.5</td></tr><tr><td>Thereafter</td><td>15.4</td><td>1.7</td><td>9.0</td><td>0.7</td><td>1.8</td></tr><tr><td>Future minimum lease payments</td><td>$ 71.3</td><td>$ 9.6</td><td>$ 43.3</td><td>$ 3.4</td><td>$ 4.9</td></tr></table>

<table><tr><td>Capital Leases (Millions of Dollars)</td><td>Eversource</td><td>CL&amp;P</td><td>PSNH</td></tr><tr><td>2016</td><td>$ 2.2</td><td>$ 1.9</td><td>$ 0.3</td></tr><tr><td>2017</td><td>2.1</td><td>1.9</td><td>0.2</td></tr><tr><td>2018</td><td>2.1</td><td>2.0</td><td>0.1</td></tr><tr><td>2019</td><td>2.0</td><td>2.0</td><td>-</td></tr><tr><td>2020</td><td>2.0</td><td>2.0</td><td>-</td></tr><tr><td>Thereafter</td><td>1.4</td><td>1.4</td><td>-</td></tr><tr><td>Future minimum lease payments</td><td>11.8</td><td>11.2</td><td>0.6</td></tr><tr><td>Less amount representing interest</td><td>3.6</td><td>3.6</td><td>-</td></tr><tr><td>Present value of future minimum lease payments</td><td>$ 8.2</td><td>$ 7.6</td><td>$ 0.6</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.



## 13. 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 CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections. The fair value of long-term debt 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="4">As of December 31,</td></tr><tr><td colspan="2">2015</td><td colspan="2">2014</td></tr><tr><td></td><td>Carrying Amount</td><td>Fair Value</td><td>Carrying Amount</td><td>Fair Value</td></tr><tr><td>Eversource (Millions of Dollars)</td><td></td><td></td><td></td><td></td></tr><tr><td>Preferred Stock Not Subject to Mandatory Redemption</td><td>$ 155.6</td><td>$ 157.9</td><td>$ 155.6</td><td>$ 153.6</td></tr><tr><td>Long-Term Debt</td><td>9,034.5</td><td>9,425.9</td><td>8,814.0</td><td>9,451.2</td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="4">As of December 31, 2015</td></tr><tr><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td></tr><tr><td></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></tr><tr><td>Preferred Stock Not Subject to Mandatory Redemption</td><td>$ 116.2</td><td>$ 114.9</td><td>$ 43.0</td><td>$ 43.0</td></tr><tr><td>Long-Term Debt</td><td>2,763.7</td><td>3,031.6</td><td>2,029.8</td><td>2,182.4</td></tr></table>

<table><tr><td rowspan="2"></td><td colspan="4">As of December 31, 2014</td></tr><tr><td colspan="2">CL&amp;P</td><td colspan="2">NSTAR Electric</td></tr><tr><td></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></tr><tr><td>Preferred Stock Not Subject to Mandatory Redemption</td><td>$ 116.2</td><td>$ 112.0</td><td>$ 43.0</td><td>$ 41.6</td></tr><tr><td>Long-Term Debt</td><td>2,826.2</td><td>3,214.5</td><td>1,786.2</td><td>1,993.5</td></tr></table>

Effective December 31, 2015, the carrying amount of Long-Term Debt includes unamortized debt issuance costs presented as a direct reduction from the carrying amount of the debt liability, in accordance with new accounting guidance. The December 31, 2014 carrying amount of Long-Term Debt was retrospectively adjusted to conform to the current year presentation. See Note 1C, “Summary of Significant Accounting Policies – Accounting Standards,” for further information.

Derivative Instruments: Derivative instruments are carried at fair value. For further information, see Note 4, “Derivative Instruments,” to the financial statements.

Other Financial Instruments: Investments in marketable securities are carried at fair value. For further information, see Note 5, “Marketable Securities,” to the financial statements. The carrying value of other financial instruments included in current assets and current liabilities on the balance sheets, including cash and cash equivalents and special deposits, approximates their fair value due to their short-term nature.

See Note 1H, “Summary of Significant Accounting Policies - Fair Value Measurements,” for the fair value measurement policy and the fair value hierarchy.

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

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

<table><tr><td rowspan="2"></td><td colspan="6">For the Year Ended December 31, 2015</td><td colspan="6">For the Year Ended December 31, 2014</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 on Marketable Securities</td><td>Defined Benefit Plans</td><td>Total</td><td>Qualified Cash Flow hedging Instruments</td><td>Unrealized Gains on Marketable Securities</td><td>Defined Benefit Plans</td><td></td></tr><tr><td>Eversource (Millions of Dollars)</td><td>$ (12.4)</td><td>$ 0.7</td><td>$ (62.3)</td><td>$ (74.0)</td><td>$ (14.4)</td><td>$ 0.4</td><td>$ (32.0)</td><td>$ (46.0)</td><td></td><td></td><td></td><td></td></tr><tr><td>Balance as of January 1st</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>OCI Before Reclassifications</td><td>-</td><td>(2.6)</td><td>3.5</td><td>0.9</td><td>-</td><td>0.3</td><td>(34.2)</td><td>(33.9)</td><td></td><td></td><td></td><td></td></tr><tr><td>Amounts Reclassified from AOCI</td><td>2.1</td><td>-</td><td>4.2</td><td>6.3</td><td>2.0</td><td>-</td><td>3.9</td><td>5.9</td><td></td><td></td><td></td><td></td></tr><tr><td>Net OCI</td><td>2.1</td><td>(2.6)</td><td>7.7</td><td>7.2</td><td>2.0</td><td>0.3</td><td>(30.3)</td><td>(28.0)</td><td></td><td></td><td></td><td></td></tr><tr><td>Balance as of December 31st</td><td>$ (10.3)</td><td>$ (1.9)</td><td>$ (54.6)</td><td>$ (66.8)</td><td>$ (12.4)</td><td>$ 0.7</td><td>$ (62.3)</td><td>$ (74.0)</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 AOCI and is being amortized into Net Income over the term of the underlying debt instrument. CL&P, PSNH and WMECO continue to amortize interest rate swaps settled in prior years from AOCI into Interest Expense over the remaining life of the associated long-term debt. Such interest rate swaps are not material to their respective financial statements.



The amortization expense of actuarial gains and losses and prior service cost on the defined benefit plans is amortized from AOCI into Operations and Maintenance over the average future employee service period, and is reflected in amounts reclassified from AOCI.

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses that arose during the year and were recognized in AOCI. The related tax effects recognized in AOCI during 2015 and 2013 were net deferred tax liabilities of $2 million in 2015 and $11.4 million in 2013, respectively, and net deferred tax assets of $22.3 million in 2014.

The following table sets forth the amounts reclassified from AOCI by component and the impacted line item on the statements of income:

<table><tr><td rowspan="3">Eversource (Millions of Dollars)</td><td colspan="4">Amounts Reclassified from AOCI</td><td rowspan="3">Statements of Income Line Item Impacted</td></tr><tr><td colspan="3">For the Years Ended December 31,</td><td rowspan="2">2013</td></tr><tr><td>2015</td><td>2014</td><td>2013</td></tr><tr><td>Qualified Cash Flow Hedging Instruments</td><td>$ (3.5)</td><td>$ (3.4)</td><td>$ (3.4)</td><td>Interest Expense</td><td></td></tr><tr><td>Tax Effect</td><td>1.4</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>$ (2.1)</td><td>$ (2.0)</td><td>$ (2.0)</td><td></td><td></td></tr><tr><td>Defined Benefit Plan Costs:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Amortization of Actuarial Losses</td><td>$ (6.6)</td><td>$ (6.2)</td><td>$ (10.5)</td><td>Operations and Maintenance  \( {}^{(1)} \)</td><td></td></tr><tr><td>Amortization of Prior Service Cost</td><td>(0.2)</td><td>(0.2)</td><td>(0.2)</td><td>Operations and Maintenance  \( {}^{(1)} \)</td><td></td></tr><tr><td>Total Defined Benefit Plan Costs</td><td>(6.8)</td><td>(6.4)</td><td>(10.7)</td><td></td><td></td></tr><tr><td>Tax Effect</td><td>2.6</td><td>2.5</td><td>4.3</td><td>Income Tax Expense</td><td></td></tr><tr><td>Defined Benefit Plan Costs, Net of Tax</td><td>$ (4.2)</td><td>$ (3.9)</td><td>$ (6.4)</td><td></td><td></td></tr><tr><td>Total Amounts Reclassified from AOCI, Net of Tax</td><td>$ (6.3)</td><td>$ (5.9)</td><td>$ (8.4)</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, 2015, it was estimated that a pre-tax amount of $3.6 million (including $0.7 million for CL&P, $2 million for PSNH and $0.7 million for WMECO) will be reclassified from AOCI as a decrease to Net Income over the next 12 months as a result of the amortization of the interest rate swap agreements which have been settled. In addition, it is estimated that a pre-tax amount of $6 million will be reclassified from AOCI as a decrease to Net Income over the next 12 months as a result of the amortization of Pension, SERP and PBOP costs.

## 15. 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.

CL&P, NSTAR Electric, PSNH and WMECO 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, PSNH and WMECO, 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. Pursuant to the joint revolving credit agreement of Eversource, CL&P, PSNH, WMECO, Yankee Gas and NSTAR Gas, and to the NSTAR Electric revolving credit agreement, each company is required to maintain consolidated total debt to total capitalization ratio of no greater than 65 percent at the end of each fiscal quarter. As of December 31, 2015, all companies were in compliance with such covenant. The Retained Earnings balances subject to these restrictions were $2.8 billion for Eversource, $1.2 billion for CL&P, $1.6 billion for NSTAR Electric, $494.9 million for PSNH and $198.1 million for WMECO as of December 31, 2015. As of December 31, 2015, Eversource, CL&P, NSTAR Electric, PSNH, WMECO, Yankee Gas and NSTAR Gas were in compliance with all such provisions of the revolving credit agreements that may restrict the payment of dividends. PSNH is further required to reserve an additional amount under its FERC hydroelectric license conditions. As of December 31, 2015, $13.4 million of PSNH’s Retained Earnings was subject to restriction under its FERC hydroelectric license conditions and PSNH was in compliance with this provision.

## 16. COMMON SHARES

The following table sets forth the Eversource parent common shares and those of CL&P, NSTAR Electric, PSNH and WMECO that were authorized and issued as well as the respective per share par values:

<table><tr><td rowspan="2"></td><td rowspan="2">Per Share Par Value</td><td colspan="2">Authorized as of December 31, 2015 and 2014</td><td colspan="2">Issued as of December 31, 2015</td></tr><tr><td>2015</td><td>2014</td><td>2015</td><td>2014</td></tr><tr><td>Eversource</td><td>$ 5</td><td>380,000,000</td><td>333,862,615</td><td>333,359,172</td><td></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><td></td></tr><tr><td>NSTAR Electric</td><td>$ 1</td><td>100,000,000</td><td>100</td><td>100</td><td></td></tr><tr><td>PSNH</td><td>$ 1</td><td>100,000,000</td><td>301</td><td>301</td><td></td></tr><tr><td>WMECO</td><td>$ 25</td><td>1,072,471</td><td>434,653</td><td>434,653</td><td></td></tr></table>



As of December 31, 2015 and 2014, there were 16,671,366 and 16,375,835 Eversource common shares held as treasury shares, respectively. As of December 31, 2015 and 2014, Eversource common shares outstanding were 317,191,249 and 316,983,337, respectively. In May 2015, the Company repurchased 532,521 Eversource common shares at a share price of $47.94. Such shares are included in Treasury Stock on the consolidated balance sheet at their weighted average original average cost of $26.02 per share.

## 17. 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>Series</td><td>Redemption Price Per Share</td><td>Shares Outstanding as of December 31, 2015 and 2014</td><td>As of December 31, 2015</td><td>2014</td></tr><tr><td>CL&amp;P</td><td></td><td></td><td></td><td></td></tr><tr><td>$ 1.90</td><td>$ 52.50</td><td>163,912</td><td>$ 8.2</td><td>$ 8.2</td></tr><tr><td>$ 2.00</td><td>$ 54.00</td><td>336,088</td><td>16.8</td><td>16.8</td></tr><tr><td>$ 2.04</td><td>$ 52.00</td><td>100,000</td><td>5.0</td><td>5.0</td></tr><tr><td>$ 2.20</td><td>$ 52.50</td><td>200,000</td><td>10.0</td><td>10.0</td></tr><tr><td>$ 3.90</td><td>$ 50.50</td><td>160,000</td><td>8.0</td><td>8.0</td></tr><tr><td>$ 2.06</td><td>$ 51.00</td><td>200,000</td><td>10.0</td><td>10.0</td></tr><tr><td>$ 2.09</td><td>$ 51.00</td><td>100,000</td><td>5.0</td><td>5.0</td></tr><tr><td>$ 4.50</td><td>$ 50.75</td><td>104,000</td><td>5.2</td><td>5.2</td></tr><tr><td>$ 4.96</td><td>$ 50.50</td><td>100,000</td><td>5.0</td><td>5.0</td></tr><tr><td>$ 4.50</td><td>$ 50.50</td><td>160,000</td><td>8.0</td><td>8.0</td></tr><tr><td>$ 5.28</td><td>$ 51.43</td><td>200,000</td><td>10.0</td><td>10.0</td></tr><tr><td>$ 3.24</td><td>$ 51.84</td><td>300,000</td><td>15.0</td><td>15.0</td></tr><tr><td>$ 6.56</td><td>$ 51.44</td><td>200,000</td><td>10.0</td><td>10.0</td></tr><tr><td>Total CL&amp;P</td><td></td><td>2,324,000</td><td>$ 116.2</td><td>$ 116.2</td></tr><tr><td>NSTAR Electric</td><td></td><td></td><td></td><td></td></tr><tr><td>$ 4.25</td><td>$ 103.625</td><td>180,000</td><td>$ 18.0</td><td>$ 18.0</td></tr><tr><td>$ 4.78</td><td>$ 102.80</td><td>250,000</td><td>25.0</td><td>25.0</td></tr><tr><td>Total NSTAR Electric</td><td></td><td>430,000</td><td>$ 43.0</td><td>$ 43.0</td></tr><tr><td>Fair Value Adjustment due to Merger with NSTAR</td><td></td><td></td><td>(3.6)</td><td>(3.6)</td></tr><tr><td>Total Eversource - Preferred Stock of Subsidiaries</td><td></td><td></td><td>$ 155.6</td><td>$ 155.6</td></tr></table>

## 18. COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $7.5 million, $7.5 million and $7.7 million for the years ended December 31, 2015, 2014 and 2013. 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, 2015 and 2014. Common Shareholders' Equity was fully attributable to the parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest on the Eversource balance sheets.

For the years ended December 31, 2015, 2014 and 2013, there was no change in ownership of the common equity of CL&P and NSTAR Electric.



## 19. 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 during each period plus the potential dilutive effect of certain share-based compensation awards as if they were converted into common shares. For the years ended December 31, 2015, 2014 and 2013, there were 1,474,3,643 and 1,575 antidilutive share awards excluded from the computation of diluted EPS, respectively.

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>2015</td><td>2014</td><td>2013</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$     878.5</td><td>$     819.5</td><td>$     786.0</td><td></td></tr><tr><td>Weighted Average Common Shares Outstanding:</td><td></td><td></td><td></td><td></td></tr><tr><td>Basic</td><td>317,336,881</td><td>316,136,748</td><td>315,311,387</td><td></td></tr><tr><td>Dilutive Effect</td><td>1,095,806</td><td>1,280,666</td><td>899,773</td><td></td></tr><tr><td>Diluted</td><td>318,432,687</td><td>317,417,414</td><td>316,211,160</td><td></td></tr><tr><td>Basic EPS</td><td>$     2.77</td><td>$     2.59</td><td>$     2.49</td><td></td></tr><tr><td>Diluted EPS</td><td>$     2.76</td><td>$     2.58</td><td>$     2.49</td><td></td></tr></table>

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. The dilutive effect of unvested RSU and performance share awards is calculated using the treasury stock method. Assumed proceeds of these awards under the treasury stock method consist of the remaining compensation cost to be recognized and a theoretical tax benefit. The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the awards (the difference between the market value of the average awards outstanding for the period, using the average market price during the period, and the grant date market value).

The dilutive effect of stock options to purchase common shares is also calculated using the treasury stock method. Assumed proceeds for stock options consist of cash proceeds that would be received upon exercise, and a theoretical tax benefit. The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the stock options (the difference between the market value of the average stock options outstanding for the period, using the average market price during the period, and the exercise price).

## 20. SEGMENT INFORMATION

Presentation: Eversource is organized between the Electric Distribution, Electric Transmission and Natural Gas Distribution reportable segments and Other based on a combination of factors, including the characteristics of each segments' products and 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 generation activities of PSNH and WMECO.

The remainder of Eversource’s operations is presented as Other in the tables below and primarily consists of 1) the equity in earnings of Eversource parent from its subsidiaries and intercompany interest income, both of which are eliminated in consolidation, and interest expense related to the debt of Eversource parent, 2) the revenues and expenses of Eversource Service, most of which are eliminated in consolidation, 3) the operations of CYAPC and YAEC, 4) the results of Eversource Gas Transmission LLC and 5) the results of other unregulated subsidiaries, which are not part of its core business.

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 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. Each of Eversource’s subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, has one reportable segment. Eversource’s operating segments and reporting units are consistent with its reportable business segments.



Eversource’s segment information is as follows:

For the Year Ended December 31, 2015

<table><tr><td>Eversource
(Millions of Dollars)</td><td>Electric
Distribution</td><td>Natural Gas
Distribution</td><td>Electric
Transmission</td><td>Other</td><td>Eliminations</td><td>Total</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></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></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></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></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></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></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></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></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></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></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></tr><tr><td>Total Assets (as of)</td><td>$ 17,981.3</td><td>$ 3,104.5</td><td>$ 8,019.3</td><td>$ 13,256.7</td><td>$ (11,781.5)</td><td>$ 30,580.3</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></tr></table>

For the Year Ended December 31, 2014

<table><tr><td>Eversource
(Millions of Dollars)</td><td>Electric
Distribution</td><td>Natural Gas
Distribution</td><td>Electric
Transmission</td><td>Other</td><td>Eliminations</td><td>Total</td></tr><tr><td>Operating Revenues</td><td>$ 5,663.4</td><td>$ 1,007.3</td><td>$ 1,018.2</td><td>$ 790.9</td><td>$ (737.9)</td><td>$ 7,741.9</td></tr><tr><td>Depreciation and Amortization</td><td>(384.6)</td><td>(68.1)</td><td>(150.5)</td><td>(42.1)</td><td>19.9</td><td>(625.4)</td></tr><tr><td>Other Operating Expenses</td><td>(4,366.2)</td><td>(786.7)</td><td>(302.1)</td><td>(748.0)</td><td>719.3</td><td>(5,483.7)</td></tr><tr><td>Operating Income</td><td>912.6</td><td>152.5</td><td>565.6</td><td>0.8</td><td>1.3</td><td>1,632.8</td></tr><tr><td>Interest Expense</td><td>(191.6)</td><td>(34.0)</td><td>(104.1)</td><td>(36.6)</td><td>4.2</td><td>(362.1)</td></tr><tr><td>Interest Income</td><td>5.1</td><td>-</td><td>0.9</td><td>3.6</td><td>(3.6)</td><td>6.0</td></tr><tr><td>Other Income, Net</td><td>10.7</td><td>0.2</td><td>10.3</td><td>916.0</td><td>(918.6)</td><td>18.6</td></tr><tr><td>Income Tax (Expense)/Benefit</td><td>(269.7)</td><td>(46.4)</td><td>(174.5)</td><td>22.3</td><td>-</td><td>(468.3)</td></tr><tr><td>Net Income</td><td>467.1</td><td>72.3</td><td>298.2</td><td>906.1</td><td>(916.7)</td><td>827.0</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></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 462.4</td><td>$ 72.3</td><td>$ 295.4</td><td>$ 906.1</td><td>$ (916.7)</td><td>$ 819.5</td></tr><tr><td>Total Assets (as of)</td><td>$ 17,536.9</td><td>$ 3,029.3</td><td>$ 7,615.6</td><td>$ 12,664.9</td><td>$ (11,106.3)</td><td>$ 29,740.4</td></tr><tr><td>Cash Flows Used for Investments in Plant</td><td>$ 645.2</td><td>$ 176.7</td><td>$ 731.6</td><td>$ 50.2</td><td>$-</td><td>1,603.7</td></tr></table>

For the Year Ended December 31, 2013

<table><tr><td>Eversource
(Millions of Dollars)</td><td>Electric
Distribution</td><td>Natural Gas
Distribution</td><td>Electric
Transmission</td><td>Other</td><td>Eliminations</td><td>Total</td></tr><tr><td>Operating Revenues</td><td>$ 5,362.3</td><td>$ 855.8</td><td>$ 978.7</td><td>$ 777.5</td><td>$ (673.1)</td><td>$ 7,301.2</td></tr><tr><td>Depreciation and Amortization</td><td>(604.8)</td><td>(66.7)</td><td>(136.2)</td><td>(62.2)</td><td>10.2</td><td>(859.7)</td></tr><tr><td>Other Operating Expenses</td><td>(3,927.7)</td><td>(659.4)</td><td>(281.8)</td><td>(715.0)</td><td>671.8</td><td>(4,912.1)</td></tr><tr><td>Operating Income</td><td>829.8</td><td>129.7</td><td>560.7</td><td>0.3</td><td>8.9</td><td>1,529.4</td></tr><tr><td>Interest Expense</td><td>(175.0)</td><td>(33.1)</td><td>(100.3)</td><td>(35.5)</td><td>5.2</td><td>(338.7)</td></tr><tr><td>Interest Income</td><td>4.1</td><td>-</td><td>0.7</td><td>5.4</td><td>(5.6)</td><td>4.6</td></tr><tr><td>Other Income, Net</td><td>12.9</td><td>0.8</td><td>10.9</td><td>858.9</td><td>(858.2)</td><td>25.3</td></tr><tr><td>Income Tax (Expense)/Benefit</td><td>(240.0)</td><td>(36.5)</td><td>(182.1)</td><td>31.9</td><td>(0.2)</td><td>(426.9)</td></tr><tr><td>Net Income</td><td>431.8</td><td>60.9</td><td>289.9</td><td>861.0</td><td>(849.9)</td><td>793.7</td></tr><tr><td>Net Income Attributable to Noncontrolling Interests</td><td>(4.8)</td><td>-</td><td>(2.9)</td><td>-</td><td>-</td><td>(7.7)</td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>$ 427.0</td><td>$ 60.9</td><td>$ 287.0</td><td>$ 861.0</td><td>$ (849.9)</td><td>$ 786.0</td></tr><tr><td>Cash Flows Used for Investments in Plant</td><td>$ 639.0</td><td>$ 168.1</td><td>$ 618.5</td><td>$ 31.2</td><td>$-</td><td>1,456.8</td></tr></table>



## 21. GOODWILL

Eversource recorded approximately $3.2 billion of goodwill in connection with the 2012 merger with NSTAR and $0.3 billion of goodwill related to the acquisition of the parent of Yankee Gas in 2000.

Goodwill is not subject to amortization, however is subject to a fair value based assessment for impairment at least annually and whenever facts or circumstances indicate that there may be an impairment. A resulting write-down, if any, would be charged to Operating Expenses. Eversource’s reporting units for the purpose of testing goodwill for impairment are Electric Distribution, Electric Transmission and Natural Gas Distribution. These reporting units are consistent with the operating segments underlying the reportable segments identified in Note 20, “Segment Information,” to the financial statements.

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. Eversource completed its annual goodwill impairment test for each of its reporting units as of October 1, 2015 and determined that no impairment existed. There were no events subsequent to October 1, 2015 that indicated impairment of goodwill.

There were no changes to the goodwill balance or the allocation of goodwill as of December 31, 2015 or 2014. The following table presents goodwill by reportable segment:

<table><tr><td rowspan="2">(Billions of Dollars)</td><td colspan="5">As of December 31, 2015 and 2014</td></tr><tr><td>Electric Distribution</td><td>Electric Transmission</td><td>Natural Gas Distribution</td><td>Total</td><td></td></tr><tr><td>Goodwill</td><td>$ 2.5</td><td>$ 0.6</td><td>$ 0.4</td><td>$ 3.5</td><td></td></tr></table>

## 22. VARIABLE INTEREST ENTITIES

The Company’s variable interests outside of the consolidated group are not material and consist of 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 and with other independent power producers. 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 any power plant VIEs.

## 23. QUARTERLY FINANCIAL DATA (UNAUDITED)

<table><tr><td rowspan="3">Eversource (Millions of Dollars, except per share information)</td><td colspan="9">Quarter Ended</td></tr><tr><td colspan="5">2015</td><td colspan="4">2014</td></tr><tr><td>March 31,</td><td>June 30,</td><td>September 30,</td><td>December 31,</td><td>March 31,</td><td>June 30,</td><td>September 30,</td><td>Decembe</td><td>r 31,</td></tr><tr><td>Operating Revenues</td><td>$ 2,513.4</td><td>$ 1,817.1</td><td>$ 1,933.1</td><td>$ 1,691.2</td><td>$ 2,290.6</td><td>$ 1,677.6</td><td>$ 1,892.5</td><td>$ 1,881.2</td><td></td></tr><tr><td>Operating Income</td><td>497.5</td><td>412.0</td><td>469.2</td><td>385.5</td><td>467.7</td><td>294.0</td><td>440.9</td><td>430.2</td><td></td></tr><tr><td>Net Income</td><td>255.1</td><td>209.4</td><td>237.8</td><td>183.7</td><td>237.8</td><td>129.2</td><td>236.5</td><td>223.6</td><td></td></tr><tr><td>Net Income Attributable to Common Shareholders</td><td>253.3</td><td>207.5</td><td>235.9</td><td>181.8</td><td>236.0</td><td>127.4</td><td>234.6</td><td>221.5</td><td></td></tr><tr><td>Basic EPS (a)</td><td>$ 0.80</td><td>$ 0.65</td><td>$ 0.74</td><td>$ 0.57</td><td>$ 0.75</td><td>$ 0.40</td><td>$ 0.74</td><td>$ 0.69</td><td></td></tr><tr><td>Diluted EPS (a)</td><td>$ 0.80</td><td>$ 0.65</td><td>$ 0.74</td><td>$ 0.57</td><td>$ 0.74</td><td>$ 0.40</td><td>$ 0.74</td><td>$ 0.69</td><td></td></tr></table>

(a) 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="9">Quarter Ended</td></tr><tr><td colspan="5">2015</td><td colspan="4">2014</td></tr><tr><td>March 31,</td><td>June 30,</td><td>September 30,</td><td>December 31,</td><td>March 31,</td><td>June 30,</td><td>September 30,</td><td>Decembe</td><td>r 31,</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></tr><tr><td>Operating Revenues</td><td>$ 804.9</td><td>$ 666.6</td><td>$ 704.3</td><td>$ 626.9</td><td>$ 734.6</td><td>$ 587.3</td><td>$ 695.6</td><td>$ 675.1</td><td></td></tr><tr><td>Operating Income</td><td>141.8</td><td>154.0</td><td>161.1</td><td>154.2</td><td>158.0</td><td>92.1</td><td>146.2</td><td>159.0</td><td></td></tr><tr><td>Net Income</td><td>69.2</td><td>78.8</td><td>80.2</td><td>71.2</td><td>79.3</td><td>37.4</td><td>83.9</td><td>87.2</td><td></td></tr><tr><td>NSTAR Electric</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Revenues</td><td>$ 766.8</td><td>$ 617.2</td><td>$ 750.7</td><td>$ 546.6</td><td>$ 666.2</td><td>$ 561.5</td><td>$ 727.9</td><td>$ 581.1</td><td></td></tr><tr><td>Operating Income</td><td>159.5</td><td>151.4</td><td>214.2</td><td>117.7</td><td>118.4</td><td>121.5</td><td>206.6</td><td>132.0</td><td></td></tr><tr><td>Net Income</td><td>83.6</td><td>82.0</td><td>118.6</td><td>60.3</td><td>58.1</td><td>60.1</td><td>115.6</td><td>69.3</td><td></td></tr><tr><td>PSNH</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Operating Revenues</td><td>$ 284.8</td><td>$ 241.9</td><td>$ 234.4</td><td>$ 211.1</td><td>$ 299.8</td><td>$ 211.6</td><td>$ 223.7</td><td>$ 224.4</td><td></td></tr><tr><td>Operating Income</td><td>63.2</td><td>54.1</td><td>63.6</td><td>49.3</td><td>64.0</td><td>49.0</td><td>56.4</td><td>60.0</td><td></td></tr><tr><td>Net Income</td><td>32.0</td><td>27.9</td><td>32.5</td><td>22.0</td><td>32.6</td><td>24.1</td><td>28.2</td><td>29.0</td><td></td></tr><tr><td>WMECO</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>$ 152.9</td><td>$ 125.2</td><td>$ 125.1</td><td>$ 114.9</td><td>$ 137.4</td><td>$ 108.3</td><td>$ 118.1</td><td>$ 129.6</td><td></td></tr><tr><td>Operating Income</td><td>28.6</td><td>28.9</td><td>30.0</td><td>28.0</td><td>34.7</td><td>17.7</td><td>31.2</td><td>34.0</td><td></td></tr><tr><td>Net Income</td><td>13.2</td><td>14.2</td><td>15.0</td><td>14.1</td><td>18.1</td><td>7.0</td><td>14.7</td><td>18.0</td><td></td></tr></table>



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

No events that would be described in response to this item have occurred with respect to Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

## Item 9A. Controls and Procedures

Management, on behalf of Eversource, CL&P, NSTAR Electric, PSNH and WMECO, is responsible for the preparation, integrity, and fair presentation of the accompanying Consolidated 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, PSNH and WMECO, 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, PSNH and WMECO were effective as of December 31, 2015.

Management, on behalf of Eversource, CL&P, NSTAR Electric, PSNH and WMECO, evaluated the design and operation of the disclosure controls and procedures as of December 31, 2015 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, PSNH and WMECO are effective to ensure that information required to be disclosed by us in reports filed under the Securities Exchange Act of 1934 (i) is recorded, processed, summarized, and reported within the time periods specified in SEC rules and regulations and (ii) is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosures.

There have been no changes in internal controls over financial reporting for Eversource, CL&P, NSTAR Electric, PSNH and WMECO during the quarter ended December 31, 2015 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, 2015, as this information has been previously disclosed in applicable reports on Form 8-K during the fourth quarter of 2015.



## PART III

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

The information in Item 10 is provided as of February 16, 2016, except where otherwise indicated.

Certain information required by this Item 10 is omitted for NSTAR Electric, PSNH and WMECO 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 24, 2016.

## 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 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. 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 24, 2016, under the sections captioned “Compensation Discussion and Analysis,” plus related subsections, and “Compensation Committee Report,” plus related subsections following such Report.

## NSTAR ELECTRIC, PSNH and WMECO

Certain information required by this Item 11 has been omitted for NSTAR Electric, PSNH and WMECO 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 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. 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 24, 2016.

## NSTAR ELECTRIC, PSNH and WMECO

Certain information required by this Item 12 has been omitted for NSTAR Electric, PSNH and WMECO 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 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. 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, 2015, 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 (a)</td><td>Weighted-average exercise price of outstanding options, warrants and rights (b)</td><td>Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) (c)</td></tr><tr><td>Equity compensation plans approved by security holders</td><td>1,429,608</td><td>$26.47</td><td>3,748,270</td></tr><tr><td>Equity compensation plans not approved by security holders (d)</td><td>—</td><td>—</td><td>—</td></tr><tr><td>Total</td><td>1,429,608</td><td>$26.47</td><td>3,748,270</td></tr></table>

(a) Includes 171,872 common shares to be issued upon exercise of options, 729,308 common shares for distribution of restricted share units, and 528,428 performance shares issuable at target, all pursuant to the terms of our Incentive Plan.

(b) The weighted-average exercise price in Column (b) does not take into account restricted share units or performance shares, which have no exercise price.

(c) Includes 743,260 common shares issuable under our Employee Share Purchase Plan II.

(d) All of our current compensation plans under which equity securities of Eversource Energy are authorized for issuance 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 “Certain Relationships and Related Transactions” of Eversource Energy’s definitive proxy statement for solicitation of proxies, expected to be filed with the SEC on or about March 24, 2016.

## NSTAR ELECTRIC, PSNH and WMECO

Certain information required by this Item 13 has been omitted for NSTAR Electric, PSNH and WMECO 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 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. 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 24, 2016.

## CL&P, NSTAR ELECTRIC, PSNH and WMECO

The information required by this Item 14 for CL&P, NSTAR Electric, PSNH and WMECO has been omitted from this report but is set forth in the Annual Report on Form 10-K for 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. 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, 2015 and 2014

Eversource Energy (Parent) Statements of Income for the Years Ended December 31, 2015, 2014 and 2013

Eversource Energy (Parent) Statements of Comprehensive Income for the Years Ended December 31, 2015, 2014 and 2013

Eversource Energy (Parent) Statements of Cash Flows for the Years Ended December 31, 2015, 2014 and 2013

II. Valuation and Qualifying Accounts and Reserves for Eversource, CL&P, NSTAR Electric, PSNH and WMECO for 2015, 2014 and 2013

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 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. Such report is also available in the Investors section at www.eversource.com.



# EVERSOURCE ENERGY

# SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

## EVERSOURCE ENERGY

February 26, 2016

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, James J. Judge 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/ Thomas J. May</td><td>Chairman, President and Chief Executive Officer, and a Trustee (Principal Executive Officer)</td><td>February 26, 2016</td></tr><tr><td>/s/ James J. Judge</td><td>Executive Vice President and Chief Financial Officer (Principal Financial Officer)</td><td>February 26, 2016</td></tr><tr><td>/s/ Jay S. Buth</td><td>Vice President, Controller and Chief Accounting Officer</td><td>February 26, 2016</td></tr><tr><td>/s/ John S. Clarkson</td><td>Trustee</td><td>February 26, 2016</td></tr><tr><td>/s/ Cotton M. Cleveland</td><td>Trustee</td><td>February 26, 2016</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 26, 2016</td></tr><tr><td>Sanford Cloud, Jr.</td><td></td><td></td></tr><tr><td>/s/ James S. DiStasio</td><td>Trustee</td><td>February 26, 2016</td></tr><tr><td>James S. DiStasio</td><td></td><td></td></tr><tr><td>/s/ Francis A. Doyle</td><td>Trustee</td><td>February 26, 2016</td></tr><tr><td>Francis A. Doyle</td><td></td><td></td></tr></table>



<table><tr><td>/s/ Charles K. Gifford</td><td>Trustee</td><td>February 26, 2016</td></tr><tr><td>Charles K. Gifford</td><td></td><td></td></tr><tr><td>/s/ Paul A. La Camera</td><td>Trustee</td><td>February 26, 2016</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 26, 2016</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 26, 2016</td></tr><tr><td>William C. Van Faasen</td><td></td><td></td></tr><tr><td>/s/ Frederica M. Williams</td><td>Trustee</td><td>February 26, 2016</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 26, 2016</td></tr><tr><td>Dennis R. Wraase</td><td></td><td></td></tr></table>



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, PSNH and WMECO has been omitted from this report but is set forth in the Annual Report on Form 10-K for 2015 filed with the SEC on a combined basis with Eversource Energy on February 26, 2016. Such report is also available in the Investors section at www.eversource.com.

Exhibit
Number ___ Description ___

3. Articles of Incorporation and By-Laws

3.1 Declaration of Trust of Eversource Energy, as amended through April 30, 2015 (Exhibit 3.1 Eversource Energy Current Report on Form 8-K filed on April 30, 2015, File No. 001-05324)

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 $400 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)

4.2 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, 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, Public Service Company of New Hampshire and Western Massachusetts Electric Company

*4.1 Amended and Restated Credit Agreement, dated October 26, 2015, by and among Eversource Energy, CL&P, NSTAR Gas, PSNH, WMECO, and Yankee Gas Services Company and the Banks named therein, pursuant to which Bank of America, N.A. serves as Administrative Agent

10. Material Contracts

(A) Eversource Energy

10.1 Lease between The Rocky River Realty Company and Eversource Energy Service Company dated as of April 14, 1992 with respect to the Berlin, Connecticut headquarters (Exhibit 10.29.1, 1992 Eversource Energy Form 10-K, File No. 001-05324)

10.2 Amended and Restated Indenture of Mortgage and Deed of Trust between Yankee Gas Services Company and the Bank of New York Mellon Trust company, N.A. formerly Connecticut National Bank, as Trustee, dated July 1, 1989, (Composite including all amendments effective January 1, 2014) (included as Exhibit B to the Eleventh Supplemental Indenture filed as Exhibit 10, Eversource Energy Form 10-Q for the Quarter Ended March 31, 2014 filed May 2, 2014, File No. 001-05324)

10.2.1 First Supplemental Indenture of Mortgage and Deed of Trust between Yankee Gas Services Company and The Connecticut National Bank, as Trustee, dated April 1, 1992 (Yankee Energy System, Inc. Registration Statement on Form S-3, dated October 2, 1992, File No. 33-52750

10.2.2 Seventh Supplemental Indenture of Mortgage and Deed of Trust between Yankee Gas Services Company and The Bank of New York, as Successor Trustee to Fleet Bank (formerly The Connecticut National Bank) dated November 1, 2004 (Exhibit 10.5.7, 2004 Eversource Energy Form 10-K filed March 17, 2005, File No. 001-05324)



10.2.3 Eighth Supplemental Indenture of Mortgage and Deed of Trust between Yankee Gas Services Company and The Bank of New York, as Successor Trustee to Fleet Bank (formerly the Connecticut National Bank) dated July 1, 2005 (Exhibit 10.5.8, Eversource Energy Form 10-Q for the Quarter Ended June 30, 2005 filed August 8, 2005, File No. 001-05324)

10.2.4 Ninth Supplemental Indenture of Mortgage and Deed of Trust between Yankee Gas Services Company and The Bank of New York Mellon Trust Company, N.A., successor as Trustee to The Bank of New York, as successor to Fleet National Bank (formerly known as The Connecticut National Bank) dated as of October 1, 2008 (Exhibit 10-1, Eversource Energy Form 10-Q for the Quarter Ended September 30, 2008 filed November 10, 2008, File No. 001-05324)

10.2.5 Tenth Supplemental Indenture of Mortgage and Deed of Trust between Yankee Gas Services Company and The Bank of New York Mellon Trust Company, N.A., successor as Trustee to The Bank of New York, as successor to Fleet National Bank (formerly known as The Connecticut National Bank), dated as of April 1, 2010 (Exhibit 10, Eversource Energy Form 10-Q for the Quarter Ended March 31, 2010 filed May 7, 2010, File No. 001-05324)

10.2.6 Eleventh Supplemental Indenture of Mortgage and Deed of Trust between Yankee Gas Services Company and The Bank of New York Mellon Trust Company, N.A., successor as Trustee to The Bank of New York, as successor to Fleet National Bank (formerly known as The Connecticut National Bank), dated as of January 1, 2014 (Exhibit 10, Eversource Energy Form 10-Q for the Quarter Ended March 31, 2014 filed May 2, 2014, File No. 001-05324)

10.2.7 Twelfth Supplemental Indenture of Mortgage and Deed of Trust between Yankee Gas Services Company and The Bank of New York Mellon Trust Company, N.A., successor as Trustee to The Bank of New York, as successor to Fleet National Bank (formerly known as The Connecticut National Bank), dated as of September 1, 2015 (Exhibit 10, Eversource Energy Form 10-Q for the Quarter Ended September 30, 2015 filed November 6, 2015, File No. 001-05324)

 \( ^{*} \) +10.3 Eversource Energy Board of Trustees' Compensation Arrangement Summary

10.4 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, 1992 Eversource Energy Form 10-K, File No. 001-05324)

 \( ^{*} \) +10.5 Eversource Supplemental Executive Retirement Program effective as of January 1, 2015

 \( ^{*} \) +10.6 Eversource Energy Deferred Compensation Plan for Executives effective as of January 1, 2014

(B) Eversource Energy, The Connecticut Light and Power Company, Public Service Company of New Hampshire and Western Massachusetts Electric Company

10.1 Amended and Restated Form of Service Contract between each of Eversource Energy, CL&P and WMECO 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 Agreements among New England Utilities with respect to the Hydro-Quebec interconnection projects (Exhibits 10(u) and 10(v); 10(w), 10(x), and 10(y), 1990 and 1988, respectively, Form 10-K of New England Electric System, File No. 001-03446)

10.3 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)

10.3.1 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)

10.4 Eversource Energy Service Company Transmission and Ancillary Service Wholesale Revenue Allocation Methodology among The Connecticut Light and Power Company, Western Massachusetts 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)

+10.5 Amended and Restated Employment Agreement with Gregory B. Butler, effective January 1, 2009 (Exhibit 10.7, 2008 Eversource Energy Form 10-K filed February 27, 2009, File No. 001-05324)

+10.6 Amended and Restated Employment Agreement with David R. McHale, effective January 1, 2009 (Exhibit 10.8, 2008 Eversource Energy Form 10-K filed February 27, 2009, File No. 001-05324)



+10.7 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)

+10.8 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)

+10.9 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)

+10.9.1 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)

+10.9.2 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)

+10.10 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)

10.11 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)

(C) 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)

(D) Eversource Energy and NSTAR Electric Company

10.1 NSTAR Electric Company Restructuring Settlement Agreement dated July 1997, (Exhibit 10.12, Boston Edison 1997 Form 10-K filed March 30, 1998, File No. 001-02301)

10.2 Amended and Restated Power Purchase Agreement (NEA A PPA), dated August 19, 2004, by and between Boston Edison and Northeast Energy Associates L.P. (Exhibit 10.18, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.3 Amended and Restated Power Purchase Agreement (NEA B PPA), dated August 19, 2004, by and between ComElectric and Northeast Energy Associates L. P. (Exhibit 10.19, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.4 Amended and Restated Power Purchase Agreement (CECO 1 PPA), dated August 19, 2004 by and between ComElectric and Northeast Energy Associates L. P. (Exhibit 10.20, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.5 Amended and Restated Power Purchase Agreement (CECO 2 PPA), dated August 19, 2004 by and between ComElectric and Northeast Energy Associates L. P. (Exhibit 10.21, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.6 The Bellingham Execution Agreement, dated August 19, 2004 between Boston Edison, ComElectric and Northeast Energy Associates L. P. (Exhibit 10.22, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.7 Second Restated NEPOOL Agreement among NSTAR Electric and various other electric utilities operating in New England, dated August 16, 2004 (Exhibit 10.2.1.1, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.8 Transmission Operating Agreement among NSTAR Electric and various electric transmission providers in New England and ISO New England Inc., dated February 1, 2005 (Exhibit 10.2.1.2, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.9 Market Participants Service Agreement among NSTAR Electric and various other electric utilities operating in New England, NEPOOL and ISO New England Inc., dated February 1, 2005 (Exhibit 10.2.1.3, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.10 Rate Design and Funds Disbursement Agreement among NSTAR Electric and various other electric transmission providers in New England, dated February 1, 2005 (Exhibit 10.2.1.4, 2005 NSTAR Form 10-K filed February 21, 2006, File No. 001-14768)

10.11 Participants Agreement among NSTAR Electric, various electric utilities operating in New England, NEPOOL and ISO-New England, Inc., dated February 1, 2005 (Exhibit 10.2.1.4, 2006 NSTAR Form 10-K filed February 16, 2007, File No. 001-14768)

+10.12 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)



+10.12.1 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)

+10.13 Special Supplemental Executive Retirement Agreement between Boston Edison Company and Thomas J. May dated March 13, 1999, regarding Key Executive Benefit Plan and Supplemental Executive Retirement Plan (Exhibit 10.3, 1999 NSTAR Form 10-K/A filed September 9, 2000, File No. 001-14768)

+10.14 Amended and Restated Change in Control Agreement by and between NSTAR and Thomas J. May dated November 15, 2007 (Exhibit 10.5, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.15 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)

+10.15.1 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 Thomas J. May, dated January 24, 2008 (Exhibit 10.8.1, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.15.2 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 James J. Judge, dated January 24, 2008 (Exhibit 10.8.2, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.15.3 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 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)

+10.16 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)

+10.17 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)

+10.18 Amended and Restated Change in Control Agreement by and between NSTAR’s other Senior Vice Presidents and NSTAR (in form), dated November 15, 2007 (Exhibit 10.15, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.19 Amended and Restated Change in Control Agreement between NSTAR’s Vice Presidents and NSTAR (in form), dated November 15, 2007 (Exhibit 10.16, 2007 NSTAR Form 10-K filed February 11, 2008, File No. 001-14768)

+10.20 Currently effective Change in Control Agreement between NSTAR’s Vice Presidents and NSTAR (in form) (Exhibit 10.17, 2009 NSTAR Form 10-K filed February 25, 2010, File No. 001-14768)

10.21 MDTE Order approving Rate Settlement Agreement dated December 31, 2005 (Exhibit 99.2, NSTAR Current Report on Form 8-K filed January 4, 2006, File No. 001-14768)

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

10.1 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement, dated as of June 10, 2015, by and among Eversource, PNSH, the Office of Energy and Planning, Designated Advocate Staff of the New Hampshire Public Utilities Commission, the Office of Consumer Advocate, New Hampshire District 3 Senator Jeb Bradley, New Hampshire District 15 Senator Dan Feltes, the City of Berlin, New Hampshire (subject to ratification by the Berlin City Council), Local No. 1837 of the International Brotherhood of Electrical Workers, the Conservation Law Foundation, the Retail Energy Supply Association, TransCanada Power Marketing Ltd., TransCanada Hydro Northeast Inc., New England Power Generators Association, Inc., and the New Hampshire Sustainable Energy Association d/b/a NH CleanTech Council. (Exhibit 99.1, PSNH Current Report on Form 8-K filed June 11, 2015, File No. 001-06392)

 \( ^{*} $ 10.1.1 Amendment to the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement dated January 26, 2016

## (F) Eversource Energy and Western Massachusetts Electric Company

10.1 Lease and Agreement by and between WMECO and Bank of New England, N.A., with BNE Realty Leasing Corporation of North Carolina dated as of December 15, 1988 (Exhibit 10.63, 1988 Eversource Energy Form 10-K, File No. 001-05324)



 \( ^{*} $ 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 of Thomas J. May, Chairman, President and Chief Executive Officer of Eversource Energy required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated February 26, 2016

31.1 Certification of James J. Judge, Executive Vice President and Chief Financial Officer of Eversource Energy required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated February 26, 2016

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

32 Certification of Thomas J. May, Chairman, President and Chief Executive Officer of Eversource Energy and James J. Judge, Executive Vice President 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, dated February 26, 2016

 \( ^{*} $ 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, Thomas J. May, certify that:

1. I have reviewed this Annual Report on Form 10-K of Eversource Energy (the registrant);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 26, 2016

/s/ Thomas J. May

Thomas J. May

Chairman, President and Chief Executive Officer

(Principal Executive Officer)



# CERTIFICATION PURSUANT TO
SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1. I have reviewed this Annual Report on Form 10-K of Eversource Energy (the registrant);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: February 26, 2016

/s/ James J. Judge

James J. Judge

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, 2015 as filed with the Securities and Exchange Commission (the Report), we, Thomas J. May, Chairman, President and Chief Executive Officer of the registrant, and James J. Judge, 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/ Thomas J. May

Thomas J. May
Chairman, President and Chief Executive Officer

/s/ James J. Judge

James J. Judge
Executive Vice President and Chief Financial Officer

Date: February 26, 2016

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

## Thomas J. May

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

## Paul A. La Camera

Administrator,
Public Radio for WBUR Boston

## Kenneth R. Leibler

Founding Partner,
Boston Options Exchange

## 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

## Thomas J. May

Chairman of the Board,
President and Chief Executive Officer

## James J. Judge

Executive Vice President
and Chief Financial Officer

## David R. McHale

Executive Vice President
and Chief Administrative Officer

## Leon J. Olivier

Executive Vice President –
Enterprise Energy Strategy and Business
Development

## Werner J. Schweiger

Executive Vice President
and Chief Operating Officer

## Gregory B. Butler

Senior Vice President and General Counsel

## Christine M. Carmody

Senior Vice President – Human Resources

## Joseph R. Nolan, Jr.

Senior Vice President – Corporate Relations



## Shareholders

As of December 31, 2015, there were 42,655 common shareholders of record of Eversource Energy holding an aggregate of 317,191,249 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 in to:

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">2015</td><td>First</td><td>$56.83</td><td>$48.54</td><td>$0.4175</td></tr><tr><td>Second</td><td>$51.42</td><td>$45.20</td><td>$0.4175</td></tr><tr><td>Third</td><td>$52.15</td><td>$44.64</td><td>$0.4175</td></tr><tr><td>Fourth</td><td>$52.85</td><td>$48.18</td><td>$0.4175</td></tr><tr><td rowspan="4">2014</td><td>First</td><td>$45.69</td><td>$41.28</td><td>$0.3925</td></tr><tr><td>Second</td><td>$47.60</td><td>$44.28</td><td>$0.3925</td></tr><tr><td>Third</td><td>$47.37</td><td>$41.92</td><td>$0.3925</td></tr><tr><td>Fourth</td><td>$56.66</td><td>$44.37</td><td>$0.3925</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."