


	UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549 FORM 10-Q
x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the Quarterly Period Ended ~~September 30, 2016~~March 31, 2017
	or
¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ____________ to ____________



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

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

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

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

1-6392	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE (a New Hampshire corporation) Energy Park 780 North Commercial Street Manchester, New Hampshire 03101-1134 Telephone: (800) 286-5000	02-0181050

0-7624	WESTERN MASSACHUSETTS ELECTRIC COMPANY (a Massachusetts corporation) 300 Cadwell Drive Springfield, Massachusetts 01104 Telephone: (800) 286-5000	04-1961130

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.



	Yes	No
	x	¨

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



	Yes	No
	x	¨

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



	Large ~~Accelerated Filer~~accelerated filer	Accelerated ~~Filer~~filer	Non-accelerated ~~Filer~~filer	Smaller reporting company	Emerging growth company

Eversource Energy	x	¨	¨	¨	¨
The Connecticut Light and Power Company	¨	¨	x	¨	¨
NSTAR Electric Company	¨	¨	x	¨	¨
Public Service Company of New Hampshire	¨	¨	x	¨	¨
Western Massachusetts Electric Company	¨	¨	x	¨	¨

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

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



	Yes	No

Eversource Energy	¨	x
The Connecticut Light and Power Company	¨	x
NSTAR Electric Company	¨	x
Public Service Company of New Hampshire	¨	x
Western Massachusetts Electric Company	¨	x

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



Company - Class of Stock	Outstanding as of ~~October 31, 2016~~
~~Eversource Energy~~ ~~Common shares, $5.00 par value~~	~~316,885,808 shares~~April 30, 2017

Eversource Energy Common Shares, $5.00 par value	316,885,808 shares
The Connecticut Light and Power Company Common ~~stock,~~Stock, $10.00 par value	6,035,205 shares

NSTAR Electric Company Common ~~stock,~~Stock, $1.00 par value	100 shares

Public Service Company of New Hampshire Common ~~stock,~~Stock, $1.00 par value	301 shares

Western Massachusetts Electric Company Common ~~stock,~~Stock, $25.00 par value	434,653 shares

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.

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

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-Q. 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:



Current or former Eversource Energy companies, segments or investments:
Eversource, ES or the Company	Eversource Energy and subsidiaries
Eversource parent or ES parent	Eversource Energy, a public utility holding company
ES parent and other companies	ES parent and other companies are comprised of Eversource parent, Eversource Service 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
CL&P	The Connecticut Light and Power Company
NSTAR Electric	NSTAR Electric Company
PSNH	Public Service Company of New Hampshire
WMECO	Western Massachusetts Electric Company
NSTAR Gas	NSTAR Gas Company
Yankee Gas	Yankee Gas Services Company
NPT	Northern Pass Transmission LLC
Eversource Service	Eversource Energy Service Company
CYAPC	Connecticut Yankee Atomic Power Company
MYAPC	Maine Yankee Atomic Power Company
YAEC	Yankee Atomic Electric Company
Yankee Companies	CYAPC, YAEC and MYAPC
Regulated companies	The Eversource Regulated companies are comprised of the electric distribution and transmission businesses of CL&P, NSTAR Electric, PSNH, and WMECO, the natural gas distribution businesses of Yankee Gas and NSTAR Gas, the generation activities of PSNH and WMECO, and NPT

Regulators:
DEEP	Connecticut Department of Energy and Environmental Protection
DOE	U.S. Department of Energy
DOER	Massachusetts Department of Energy Resources
DPU	Massachusetts Department of Public Utilities
EPA	U.S. Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
ISO-NE	ISO New England, Inc., the New England Independent System Operator
MA DEP	Massachusetts Department of Environmental Protection
NHPUC	New Hampshire Public Utilities Commission
PURA	Connecticut Public Utilities Regulatory Authority
SEC	U.S. Securities and Exchange Commission
SJC	Supreme Judicial Court of Massachusetts

Other Terms and Abbreviations:
Access Northeast	A project being developed jointly by Eversource, Enbridge, Inc. ("Enbridge"), and National Grid plc ("National Grid") through Algonquin Gas Transmission, LLC to bring needed additional natural gas pipeline and storage capacity to New England.
ADIT	Accumulated Deferred Income Taxes
AFUDC	Allowance For Funds Used During Construction
~~AOCI~~AOCL	Accumulated Other Comprehensive ~~Income/(Loss)~~Loss
ARO	Asset Retirement Obligation
Bay State Wind	A proposed offshore wind project being developed off the coast of Massachusetts
Bcf	Billion cubic feet
C&LM	Conservation and Load Management
CfD	Contract for Differences
Clean Air Project	The construction of a wet flue gas desulphurization system, known as ~~“scrubber~~"scrubber technology,”" to reduce mercury emissions of the Merrimack coal-fired generation station in Bow, New Hampshire
~~Clean Energy Connect Project~~	~~The Clean Energy Connect project is a planned transmission, wind and hydro generation project that Eversource plans to co-develop with experienced renewable generation companies.~~
CO₂	Carbon dioxide
CPSL	Capital Projects Scheduling List
CTA	Competitive Transition Assessment
CWIP	Construction Work in Progress
EDC	Electric distribution company
EPS	Earnings Per Share
ERISA	Employee Retirement Income Security Act of 1974
~~ESOP~~	~~Employee Stock Ownership Plan~~
~~ESPP~~	~~Employee Share Purchase Plan~~



ESOP	Employee Stock Ownership Plan
ESPP	Employee Share Purchase Plan
Eversource ~~2015~~2016 Form 10-K	The Eversource Energy and Subsidiaries ~~2015~~2016 combined Annual Report on Form 10-K as filed with the SEC
FERC ALJ	FERC Administrative Law Judge
Fitch	Fitch Ratings
FMCC	Federally Mandated Congestion Charge
FTR	Financial Transmission Rights
GAAP	Accounting principles generally accepted in the United States of America
GSC	Generation Service Charge
GSRP	Greater Springfield Reliability Project
GWh	Gigawatt-Hours
HQ	Hydro-Québec, a corporation ~~wholly owned~~wholly-owned by the Québec government, including its divisions that produce, transmit and distribute electricity in Québec, Canada
HVDC	High voltage direct current
Hydro Renewable Energy	Hydro Renewable Energy, Inc., a ~~wholly owned~~wholly-owned subsidiary of Hydro-Québec
IPP	Independent Power Producers
ISO-NE Tariff	ISO-NE FERC Transmission, Markets and Services Tariff
kV	Kilovolt
kVa	Kilovolt-ampere
kW	Kilowatt (equal to one thousand watts)
kWh	Kilowatt-Hours (the basic unit of electricity energy equal to one kilowatt of power supplied for one hour)
LBR	Lost Base Revenue
LNG	Liquefied natural gas
LRS	Supplier of last resort service
McF	Million cubic feet
MGP	Manufactured Gas Plant
MMBtu	One million British thermal units
~~Moody’s~~Moody's	~~Moody’s~~Moody's Investors Services, Inc.
MW	Megawatt
MWh	Megawatt-Hours
NEEWS	New England East-West Solution
NETOs	New England Transmission Owners
Northern Pass	The ~~high voltage direct current~~high-voltage direct-current and associated alternating-current transmission line project from Canada into New Hampshire
NOx	Nitrogen oxides
OCI	Other Comprehensive Income/(Loss)
PAM	Pension and PBOP Rate Adjustment Mechanism
PBOP	Postretirement Benefits Other Than Pension
PBOP Plan	Postretirement Benefits Other Than Pension Plan that provides certain retiree benefits, primarily medical, dental and life insurance
PCRBs	Pollution Control Revenue Bonds
Pension Plan	Single uniform noncontributory defined benefit retirement plan
PPA	Pension Protection Act
RECs	Renewable Energy Certificates
Regulatory ROE	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
RNS	Regional Network Service
ROE	Return on Equity
RRB	Rate Reduction Bond or Rate Reduction Certificate
RSUs	Restricted share units
S&P	Standard & ~~Poor’s~~Poor's Financial Services LLC
SBC	Systems Benefits Charge
SCRC	Stranded Cost Recovery Charge
SERP	Supplemental Executive Retirement Plans and non-qualified defined benefit retirement plans
SIP	Simplified Incentive Plan
SO₂	Sulfur dioxide
SS	Standard service
TCAM	Transmission Cost Adjustment Mechanism
TSA	Transmission Service Agreement
UI	The United Illuminating Company

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

TABLE OF CONTENTS



		Page
PART I – FINANCIAL INFORMATION

ITEM 1.	Financial Statements (Unaudited)

	Eversource Energy and Subsidiaries (Unaudited)
	Condensed Consolidated Balance Sheets	1
	Condensed Consolidated Statements of Income	2
	Condensed Consolidated Statements of Comprehensive Income	2
	Condensed Consolidated Statements of Cash Flows	3

	The Connecticut Light and Power Company (Unaudited)
	Condensed Balance Sheets	4
	Condensed Statements of Income	5
	Condensed Statements of Comprehensive Income	5
	Condensed Statements of Cash Flows	6

	NSTAR Electric Company and Subsidiary (Unaudited)
	Condensed Consolidated Balance Sheets	7
	Condensed Consolidated Statements of Income	8
	Condensed Consolidated Statements of Comprehensive Income	8
	Condensed Consolidated Statements of Cash Flows	9

	Public Service Company of New Hampshire and Subsidiary (Unaudited)
	Condensed Consolidated Balance Sheets	10
	Condensed Consolidated Statements of Income	11
	Condensed Consolidated Statements of Comprehensive Income	11
	Condensed Consolidated Statements of Cash Flows	12

	Western Massachusetts Electric Company (Unaudited)
	Condensed Balance Sheets	13
	Condensed Statements of Income	14
	Condensed Statements of Comprehensive Income	14
	Condensed Statements of Cash Flows	15

	Combined Notes to Condensed Financial Statements (Unaudited)	16

ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations
	Eversource Energy and Subsidiaries	3432
	The Connecticut Light and Power Company	4945
	NSTAR Electric Company and Subsidiary	5247
	Public Service Company of New Hampshire and Subsidiary	5549
	Western Massachusetts Electric Company	5751

ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	5953

ITEM 4.	Controls and Procedures	5953

PART II – OTHER INFORMATION

ITEM 1.	Legal Proceedings	6054

ITEM 1A.	Risk Factors	6054

ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6054

ITEM 6.	Exhibits	6155

SIGNATURES		6357

iii

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	September 30, 2016			December 31, 2015			As of March 31, 2017			As of December 31, 2016

ASSETS
Current Assets:
Cash and Cash Equivalents	$	40,056		$	23,947		$	45,763		$	30,251
Receivables, Net	963,279			775,480			879,451			847,301
Unbilled Revenues	187,749			202,647			166,710			168,490
Taxes Receivable	4,527			305,359
Fuel, Materials, Supplies and Inventory	311,051			336,476			361,779			328,721
Regulatory Assets	752,378			845,843			875,037			887,625
Prepayments and Other Current Assets	155,612			129,034			182,659			215,284
Total Current Assets	2,414,652			2,618,786			2,511,399			2,477,672

Property, Plant and Equipment, Net	20,807,943			19,892,441			21,641,898			21,350,510

Deferred Debits and Other Assets:
Regulatory Assets	3,469,879			3,737,960			3,564,700			3,638,688
Goodwill	3,519,401			3,519,401			3,519,401			3,519,401
Marketable Securities	525,809			516,478			561,585			544,642
Other Long-Term Assets	344,653			295,243			556,193			522,260
Total Deferred Debits and Other Assets	7,859,742			8,069,082			8,201,879			8,224,991

Total Assets	$	31,082,337		$	30,580,309		$	32,355,176		$	32,053,173

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	734,500		$	1,160,953		$	975,500		$	1,148,500
Long-Term Debt - Current Portion	373,883			228,883
Long-Term Debt – Current Portion							773,883			773,883
Accounts Payable	679,505			813,646			745,856			884,521
Obligations to Third Party Suppliers	166,845			128,564
Regulatory Liabilities	160,442			107,759			199,160			146,787
Other Current Liabilities	526,853			549,985			639,366			684,914
Total Current Liabilities	2,642,028			2,989,790			3,333,765			3,638,605

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	5,442,856			5,147,678			5,758,603			5,607,207
Regulatory Liabilities	550,162			513,595			692,989			702,255
Derivative Liabilities	427,382			337,102			415,795			413,676
Accrued Pension, SERP and PBOP	1,116,240			1,407,288
Accrued Pension and SERP							1,077,593			1,141,514
Other Long-Term Liabilities	875,589			871,499			848,776			853,260
Total Deferred Credits and Other Liabilities	8,412,229			8,277,162			8,793,756			8,717,912

Capitalization:
Long-Term Debt	9,235,128			8,805,574			9,267,891			8,829,354

Noncontrolling Interest - Preferred Stock of Subsidiaries	155,568			155,568			155,568			155,568

Equity:
Common Shareholders’ Equity:
Common Shareholders' Equity:
Common Shares	1,669,392			1,669,313			1,669,392			1,669,392
Capital Surplus, Paid In	6,256,580			6,262,368			6,230,608			6,250,224
Retained Earnings	3,087,006			2,797,355			3,284,108			3,175,171
Accumulated Other Comprehensive Loss	(65,617		)	(66,844		)	(62,141		)	(65,282		)
Treasury Stock	(309,977		)	(309,977		)	(317,771		)	(317,771		)
Common Shareholders’ Equity	10,637,384			10,352,215
Common Shareholders' Equity							10,804,196			10,711,734
Total Capitalization	20,028,080			19,313,357			20,227,655			19,696,656

Total Liabilities and Capitalization	$	31,082,337		$	30,580,309		$	32,355,176		$	32,053,173

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

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,					For the Nine Months Ended September 30,				For the Three Months Ended March 31,
(Thousands of Dollars, Except Share Information)	2016		2015			2016		2015		2017		2016

Operating Revenues	$	2,039,706	$	1,933,105		$	5,862,525	$	6,263,597	$	2,105,135	$	2,055,635

Operating Expenses:
Purchased Power, Fuel and Transmission	665,810		702,640			2,001,929		2,549,807		753,649		754,859
Operations and Maintenance	324,734		327,283			965,584		977,306		330,265		320,136
Depreciation	181,288		167,884			531,781		495,389		186,805		173,986
Amortization of Regulatory Assets/(Liabilities), Net	43,942		(16,851		)	56,223		42,587
Amortization of Regulatory Assets, Net										24,017		20,997
Energy Efficiency Programs	149,121		132,107			405,962		380,559		146,158		137,175
Taxes Other Than Income Taxes	164,942		150,804			479,219		439,221		155,222		159,946
Total Operating Expenses	1,529,837		1,463,867			4,440,698		4,884,869		1,596,116		1,567,099
Operating Income	509,869		469,238			1,421,827		1,378,728		509,019		488,536
Interest Expense	99,865		92,534			298,568		279,635		103,429		98,212
Other Income, Net	13,641		5,241			23,689		23,866		13,577		2,011
Income Before Income Tax Expense	423,645		381,945			1,146,948		1,122,959		419,167		392,335
Income Tax Expense	156,446		144,146			428,186		420,640		157,829		146,302
Net Income	267,199		237,799			718,762		702,319		261,338		246,033
Net Income Attributable to Noncontrolling Interests	1,880		1,879			5,639		5,639		1,880		1,880
Net Income Attributable to Common Shareholders	$	265,319	$	235,920		$	713,123	$	696,680	$	259,458	$	244,153

Basic Earnings Per Common Share	$	0.83	$	0.74		$	2.24	$	2.20

Diluted Earnings Per Common Share	$	0.83	$	0.74		$	2.24	$	2.19
Basic and Diluted Earnings Per Common Share										$	0.82	$	0.77

Dividends Declared Per Common Share	$	0.45	$	0.42		$	1.34	$	1.25	$	0.48	$	0.45

Weighted Average Common Shares Outstanding:
Basic	317,787,836		317,452,212			317,696,823		317,296,107		317,463,151		317,517,141
Diluted	318,577,079		318,405,269			318,511,609		318,396,042		318,124,536		318,481,050

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

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

For the Three Months Ended September 30, For the Nine Months Ended September 30,
(Thousands of Dollars) 2016 2015 2016 2015

Net Income $ 267,199
$ 237,799
$ 718,762
$ 702,319
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments 534
526
1,602
1,544
Changes in Unrealized Gains/(Losses) on
Marketable Securities 946
(2,803 ) 2,271
(3,919 )
Changes in Funded Status of Pension,
SERP and PBOP Benefit Plans (1,733 ) 764
(2,646 ) 2,838
Other Comprehensive (Loss)/Income, Net of Tax (253 ) (1,513 ) 1,227
463
Comprehensive Income Attributable to
Noncontrolling Interests (1,880 ) (1,879 ) (5,639 ) (5,639 )
Comprehensive Income Attributable to
Common Shareholders $ 265,066
$ 234,407
$ 714,350
$ 697,143



	For the Three Months Ended March 31,
(Thousands of Dollars)	2017			2016

Net Income	$	261,338		$	246,033
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	534			534
Changes in Unrealized Gains on Marketable Securities	1,645			264
Changes in Funded Status of Pension, SERP and PBOP Benefit Plans	962			871
Other Comprehensive Income, Net of Tax	3,141			1,669
Comprehensive Income Attributable to Noncontrolling Interests	(1,880		)	(1,880		)
Comprehensive Income Attributable to Common Shareholders	$	262,599		$	245,822

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

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Three Months Ended March 31,
(Thousands of Dollars)	2016			2015			2017			2016

Operating Activities:
Net Income	$	718,762		$	702,319		$	261,338		$	246,033
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	531,781			495,389			186,805			173,986
Deferred Income Taxes	301,413			153,353			141,398			141,132
Pension, SERP and PBOP Expense	31,627			71,802
Pension, SERP and PBOP Expense, Net							5,828			11,583
Pension and PBOP Contributions	(121,854		)	(162,880		)	(45,700		)	(30,383		)
Regulatory Overrecoveries, Net	152,808			31,874
Regulatory Over/(Under) Recoveries, Net							56,734			(82,772		)
Amortization of Regulatory Assets, Net	56,223			42,587			24,017			20,997
Other	(27,671		)	(39,822		)	(42,428		)	(16,532		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(191,454		)	(148,442		)	(50,251		)	(133,965		)
Fuel, Materials, Supplies and Inventory	25,425			47,380			(33,058		)	(22,748		)
Taxes Receivable/Accrued, Net	347,898			383,047			32,313			279,106
Accounts Payable	(121,513		)	(233,660		)	(57,701		)	(76,317		)
Other Current Assets and Liabilities, Net	(53,077		)	8,370			(42,793		)	(10,156		)
Net Cash Flows Provided by Operating Activities	1,650,368			1,351,317			436,502			499,964

Investing Activities:
Investments in Property, Plant and Equipment	(1,359,171		)	(1,177,285		)	(523,560		)	(431,472		)
Proceeds from Sales of Marketable Securities	444,209			556,582			154,772			136,805
Purchases of Marketable Securities	(437,197		)	(535,044		)	(149,688		)	(135,427		)
Other Investing Activities	(9,463		)	(2,769		)	(11,281		)	5,494
Net Cash Flows Used in Investing Activities	(1,361,622		)	(1,158,516		)	(529,757		)	(424,600		)

Financing Activities:
Cash Dividends on Common Shares	(423,471		)	(397,363		)	(150,521		)	(141,157		)
Cash Dividends on Preferred Stock	(5,639		)	(5,639		)	(1,880		)	(1,880		)
Decrease in Notes Payable	(426,453		)	(387,575		)	(173,000		)	(391,453		)
Issuance of Long-Term Debt	800,000			825,000			600,000			500,000
Retirements of Long-Term Debt	(200,000		)	(216,700		)	(150,000		)	—
Other Financing Activities	(17,074		)	(13,446		)	(15,832		)	(13,855		)
Net Cash Flows Used in Financing Activities	(272,637		)	(195,723		)
Net Increase/(Decrease) in Cash and Cash Equivalents	16,109			(2,922		)
Net Cash Flows Provided by/(Used in) Financing Activities							108,767			(48,345		)
Net Increase in Cash and Cash Equivalents							15,512			27,019
Cash and Cash Equivalents - Beginning of Period	23,947			38,703			30,251			23,947
Cash and Cash Equivalents - End of Period	$	40,056		$	35,781		$	45,763		$	50,966

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	September 30, 2016			December 31, 2015			As of March 31, 2017		As of December 31, 2016

ASSETS
Current Assets:
Cash	$	8,607		$	1,057		$	15,315	$	6,579
Receivables, Net	425,421			352,536			349,714		359,132
Accounts Receivable from Affiliated Companies	24,012			21,214			17,184		16,851
Unbilled Revenues	87,771			99,879			51,069		50,373
Taxes Receivable	—			137,643
Materials and Supplies	51,598			43,124
Materials, Supplies and Inventory							56,432		52,050
Regulatory Assets	267,733			268,318			370,083		335,526
Prepaid Property Taxes	54,619			18,019
Prepayments and Other Current Assets	15,439			14,215			52,406		52,670
Total Current Assets	935,200			956,005			912,203		873,181

Property, Plant and Equipment, Net	7,453,200			7,156,809			7,754,894		7,632,392

Deferred Debits and Other Assets:
Regulatory Assets	1,398,610			1,369,028			1,367,486		1,391,564
Other Long-Term Assets	131,049			111,115			140,157		137,907
Total Deferred Debits and Other Assets	1,529,659			1,480,143			1,507,643		1,529,471

Total Assets	$	9,918,059		$	9,592,957		$	10,174,740	$	10,035,044

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	108,500		$	277,400		$	3,400	$	80,100
Long-Term Debt - Current Portion	250,000			—
Long-Term Debt – Current Portion							100,000		250,000
Accounts Payable	228,744			267,764			281,414		289,532
Accounts Payable to Affiliated Companies	63,718			66,456			67,250		88,075
Obligations to Third Party Suppliers	66,952			60,746			51,885		55,520
Accrued Taxes	71,238			12,068
Regulatory Liabilities	75,654			61,155			58,946		47,055
Derivative Liabilities	85,342			91,820			70,739		77,765
Other Current Liabilities	94,762			98,563			127,869		120,399
Total Current Liabilities	1,044,910			935,972			761,503		1,008,446

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,931,369			1,820,865			2,037,638		1,987,661
Regulatory Liabilities	89,599			74,830			101,241		100,138
Derivative Liabilities	426,053			336,189			415,187		412,750
Accrued Pension, SERP and PBOP	274,456			271,056			296,105		300,208
Other Long-Term Liabilities	130,477			133,446			123,931		123,244
Total Deferred Credits and Other Liabilities	2,851,954			2,636,386			2,974,102		2,924,001

Capitalization:
Long-Term Debt	2,515,444			2,763,682			2,813,151		2,516,010

Preferred Stock Not Subject to Mandatory Redemption	116,200			116,200			116,200		116,200

Common Stockholder’s Equity:
Common Stockholder's Equity:
Common Stock	60,352			60,352			60,352		60,352
Capital Surplus, Paid In	2,056,402			1,910,663			2,110,726		2,110,714
Retained Earnings	1,272,962			1,170,278			1,338,592		1,299,374
Accumulated Other Comprehensive Loss	(165		)	(576		)
Common Stockholder’s Equity	3,389,551			3,140,717
Accumulated Other Comprehensive Income/(Loss)							114		(53		)
Common Stockholder's Equity							3,509,784		3,470,387
Total Capitalization	6,021,195			6,020,599			6,439,135		6,102,597

Total Liabilities and Capitalization	$	9,918,059		$	9,592,957		$	10,174,740	$	10,035,044

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,					For the Nine Months Ended September 30,				For the Three Months Ended March 31,
(Thousands of Dollars)	2016		2015			2016		2015		2017		2016

Operating Revenues	$	760,037	$	704,262		$	2,175,141	$	2,175,733	$	732,310	$	735,317

Operating Expenses:
Purchased Power and Transmission	253,509		274,762			760,613		861,562		244,938		272,600
Operations and Maintenance	123,034		122,280			356,409		358,324		128,226		110,843
Depreciation	57,675		54,809			172,175		159,903		59,751		56,969
Amortization of Regulatory Assets/(Liabilities), Net	23,418		(22,859		)	30,308		17,917
Amortization of Regulatory Assets, Net										12,803		9,878
Energy Efficiency Programs	44,381		42,590			117,969		119,360		36,591		38,090
Taxes Other Than Income Taxes	81,948		71,563			227,981		201,743		73,979		75,465
Total Operating Expenses	583,965		543,145			1,665,455		1,718,809		556,288		563,845
Operating Income	176,072		161,117			509,686		456,924		176,022		171,472
Interest Expense	36,083		36,716			108,561		109,463		34,964		36,498
Other Income, Net	3,669		2,356			10,881		8,576		2,756		936
Income Before Income Tax Expense	143,658		126,757			412,006		356,037		143,814		135,910
Income Tax Expense	57,026		46,569			155,453		127,845		53,606		48,863
Net Income	$	86,632	$	80,188		$	256,553	$	228,192	$	90,208	$	87,047

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

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended September 30,					For the Nine Months Ended September 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	2016		2015			2016		2015			2017		2016

Net Income	$	86,632	$	80,188		$	256,553	$	228,192		$	90,208	$	87,047
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	111		111			333		333			111		111
Changes in Unrealized Gains/(Losses) on Marketable Securities	33		(98		)	78		(137		)
Changes in Unrealized Gains on Marketable Securities											56		9
Other Comprehensive Income, Net of Tax	144		13			411		196			167		120
Comprehensive Income	$	86,776	$	80,201		$	256,964	$	228,388		$	90,375	$	87,167

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Three Months Ended March 31,
(Thousands of Dollars)	2016			2015			2017			2016

Operating Activities:
Net Income	$	256,553		$	228,192		$	90,208		$	87,047
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	172,175			159,903			59,751			56,969
Deferred Income Taxes	109,637			(11,011		)	47,864			58,363
Pension, SERP, and PBOP Expense, Net of PBOP Contributions	4,825			10,654
Regulatory Overrecoveries, Net	33,492			12,504
Regulatory Underrecoveries, Net							(18,734		)	(70,195		)
Amortization of Regulatory Assets, Net	30,308			17,917			12,803			9,878
Other	(14,873		)	(13,048		)	(2,373		)	2,216
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(100,074		)	(91,842		)	(1,280		)	(37,501		)
Taxes Receivable/Accrued, Net	197,422			160,031			32,920			141,951
Accounts Payable	(30,168		)	(20,485		)	(16,957		)	(5,040		)
Other Current Assets and Liabilities, Net	(44,908		)	(31,044		)	(32,576		)	(22,533		)
Net Cash Flows Provided by Operating Activities	614,389			421,771			171,626			221,155

Investing Activities:
Investments in Property, Plant and Equipment	(438,518		)	(359,339		)	(181,601		)	(147,131		)
Proceeds from the Sale of Property, Plant and Equipment	9,047			—			—			9,047
Other Investing Activities	310			(740		)	32			49
Net Cash Flows Used in Investing Activities	(429,161		)	(360,079		)	(181,569		)	(138,035		)

Financing Activities:
Cash Dividends on Common Stock	(149,700		)	(147,000		)	(49,600		)	(49,900		)
Cash Dividends on Preferred Stock	(4,169		)	(4,169		)	(1,390		)	(1,390		)
Capital Contributions from Eversource Parent	145,700			105,000			—			145,700
Issuance of Long-Term Debt	—			300,000			300,000			—
Retirement of Long-Term Debt	—			(162,000		)	(150,000		)	—
Decrease in Notes Payable to Eversource Parent	(168,900		)	(133,400		)	(76,700		)	(161,900		)
Other Financing Activities	(609		)	(9,072		)	(3,631		)	(205		)
Net Cash Flows Used in Financing Activities	(177,678		)	(50,641		)
Net Cash Flows Provided by/(Used in) Financing Activities							18,679			(67,695		)
Net Increase in Cash	7,550			11,051			8,736			15,425
Cash - Beginning of Period	1,057			2,356			6,579			1,057
Cash - End of Period	$	8,607		$	13,407		$	15,315		$	16,482

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	September 30, 2016		December 31, 2015		As of March 31, 2017		As of December 31, 2016

ASSETS
Current Assets:
Cash and Cash Equivalents	$	6,154	$	3,346	$	2,448	$	3,494
Receivables, Net	300,692		229,936		264,337		257,557
Accounts Receivable from Affiliated Companies	8,891		4,034		4,565		8,581
Unbilled Revenues	40,370		29,464		28,393		31,632
Taxes Receivable	—		70,236		2,884		39,738
Materials, Supplies and Inventory	44,827		75,487		94,338		62,288
Regulatory Assets	259,213		348,408		276,476		289,400
Prepayments and Other Current Assets	11,025		11,448		17,109		14,906
Total Current Assets	671,172		772,359		690,550		707,596

Property, Plant and Equipment, Net	5,875,874		5,655,458		6,108,944		6,051,835

Deferred Debits and Other Assets:
Regulatory Assets	1,043,237		1,112,977		1,051,090		1,057,746
Prepaid PBOP					100,609		95,073
Other Long-Term Assets	118,924		62,467		63,371		60,572
Total Deferred Debits and Other Assets	1,162,161		1,175,444		1,215,070		1,213,391

Total Assets	$	7,709,207	$	7,603,261	$	8,014,564	$	7,972,822

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	36,000	$	62,500	$	174,500	$	126,500
Long-Term Debt - Current Portion	—		200,000
Long-Term Debt – Current Portion					400,000		400,000
Accounts Payable	194,894		228,250		177,110		232,599
Accounts Payable to Affiliated Companies	64,912		38,648		96,924		91,532
Obligations to Third Party Suppliers	87,183		56,718		60,650		55,863
Renewable Portfolio Standards Compliance Obligations	56,741		104,847		94,800		75,571
Accrued Taxes	78,429		6,585
Regulatory Liabilities	48,842		3,281		62,154		63,653
Other Current Liabilities	56,879		65,422		54,166		71,122
Total Current Liabilities	623,880		766,251		1,120,304		1,116,840

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,795,763		1,760,339		1,866,259		1,836,292
Regulatory Liabilities	357,168		264,352		390,458		391,823
Accrued Pension, SERP and PBOP	91,788		209,153
Accrued Pension and SERP					99,491		111,827
Other Long-Term Liabilities	125,137		120,939		125,640		123,194
Total Deferred Credits and Other Liabilities	2,369,856		2,354,783		2,481,848		2,463,136

Capitalization:
Long-Term Debt	2,077,955		1,829,766		1,678,514		1,678,116

Preferred Stock Not Subject to Mandatory Redemption	43,000		43,000		43,000		43,000

Common Stockholder’s Equity:
Common Stockholder's Equity:
Common Stock	—		—		—		—
Capital Surplus, Paid In	1,020,378		995,378		1,045,378		1,045,378
Retained Earnings	1,573,624		1,613,538		1,645,156		1,625,984
Accumulated Other Comprehensive Income	514		545		364		368
Common Stockholder’s Equity	2,594,516		2,609,461
Common Stockholder's Equity					2,690,898		2,671,730
Total Capitalization	4,715,471		4,482,227		4,412,412		4,392,846

Total Liabilities and Capitalization	$	7,709,207	$	7,603,261	$	8,014,564	$	7,972,822

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,				For the Nine Months Ended September 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	2016		2015		2016		2015			2017		2016

Operating Revenues	$	780,462	$	750,724	$	1,985,979	$	2,134,728		$	603,779	$	614,216

Operating Expenses:
Purchased Power and Transmission	291,382		299,040		764,907		984,035			233,093		254,336
Operations and Maintenance	96,282		83,486		279,932		228,740			88,351		94,696
Depreciation	54,695		49,101		159,151		146,818			55,216		51,886
Amortization of Regulatory Assets/(Liabilities), Net	9,621		2,257		18,275		(10,643		)
Amortization of Regulatory Assets, Net										4,977		4,683
Energy Efficiency Programs	84,717		67,693		212,882		164,843			67,312		66,243
Taxes Other Than Income Taxes	35,050		34,982		101,800		95,821			27,393		32,555
Total Operating Expenses	571,747		536,559		1,536,947		1,609,614			476,342		504,399
Operating Income	208,715		214,165		449,032		525,114			127,437		109,817
Interest Expense	21,101		18,992		62,206		57,218			22,029		20,889
Other Income, Net	5,022		513		7,524		3,649
Other Income/(Loss), Net										3,249		(334		)
Income Before Income Tax Expense	192,636		195,686		394,350		471,545			108,657		88,594
Income Tax Expense	75,440		77,062		154,493		187,397			42,495		34,101
Net Income	$	117,196	$	118,624	$	239,857	$	284,148		$	66,162	$	54,493

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

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended September 30,						For the Nine Months Ended September 30,						For the Three Months Ended March 31,
(Thousands of Dollars)	2016			2015			2016			2015			2017			2016

Net Income	$	117,196		$	118,624		$	239,857		$	284,148		$	66,162		$	54,493
Other Comprehensive Loss, Net of Tax:
Changes in Funded Status of SERP Benefit Plan	(10		)	(2		)	(31		)	(184		)	(4		)	(10		)
Other Comprehensive Loss, Net of Tax	(10		)	(2		)	(31		)	(184		)	(4		)	(10		)
Comprehensive Income	$	117,186		$	118,622		$	239,826		$	283,964		$	66,158		$	54,483

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Three Months Ended March 31,
(Thousands of Dollars)	2016			2015			2017			2016

Operating Activities:
Net Income	$	239,857		$	284,148		$	66,162		$	54,493
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	159,151			146,818			55,216			51,886
Deferred Income Taxes	40,960			54,188			29,199			32,878
Pension and PBOP Contributions, Net of Pension, SERP and PBOP Expense	(25,364		)	(1,138		)
Pension, SERP and PBOP Benefits and Contributions, Net of Expense							(10,422		)	(12,953		)
Regulatory Over/(Under) Recoveries, Net	131,774			(48,903		)	4,373			(16,746		)
Amortization of Regulatory Assets/(Liabilities), Net	18,275			(10,643		)
Amortization of Regulatory Assets, Net							4,977			4,683
Other	(20,088		)	(34,223		)	(3,691		)	(3,245		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(103,444		)	(84,587		)	(2,376		)	(29,132		)
Materials, Supplies and Inventory	30,659			21,863			(32,050		)	(40,322		)
Taxes Receivable/Accrued, Net	141,379			207,516			38,970			33,938
Accounts Payable	(22,913		)	(79,449		)	(19,025		)	1,187
Other Current Assets and Liabilities, Net	(25,942		)	46,671			2,371			19,600
Net Cash Flows Provided by Operating Activities	564,304			502,261			133,704			96,267

Investing Activities:
Investments in Property, Plant and Equipment	(327,731		)	(314,055		)	(132,105		)	(91,319		)
Other Investing Activities							(3,617		)	—
Net Cash Flows Used in Investing Activities	(327,731		)	(314,055		)	(135,722		)	(91,319		)

Financing Activities:
Cash Dividends on Common Stock	(278,300		)	(148,500		)	(46,500		)	(90,300		)
Cash Dividends on Preferred Stock	(1,470		)	(1,470		)	(490		)	(490		)
Decrease in Notes Payable	(26,500		)	(43,500		)
Issuance of Long-Term Debt	250,000			—
Retirements of Long-Term Debt	(200,000		)	(4,700		)
Capital Contributions from Eversource Parent	25,000			—
Increase in Notes Payable							48,000			86,000
Other Financing Activities	(2,495		)	—			(38		)	—
Net Cash Flows Used in Financing Activities	(233,765		)	(198,170		)
Increase/(Decrease) in Cash and Cash Equivalents	2,808			(9,964		)
Net Cash Flows Provided by/(Used in) Financing Activities							972			(4,790		)
(Decrease)/Increase in Cash and Cash Equivalents							(1,046		)	158
Cash and Cash Equivalents - Beginning of Period	3,346			12,773			3,494			3,346
Cash and Cash Equivalents - End of Period	$	6,154		$	2,809		$	2,448		$	3,504

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

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	September 30, 2016			December 31, 2015			As of March 31, 2017			As of December 31, 2016

ASSETS
Current Assets:
Cash	$	4,436		$	1,733		$	7,743		$	4,646
Receivables, Net	97,613			77,546			81,899			84,450
Accounts Receivable from Affiliated Companies	4,190			2,352			2,098			4,185
Unbilled Revenues	39,168			38,207			42,784			41,004
Taxes Receivable	7,913			43,128
Fuel, Materials, Supplies and Inventory	160,882			156,868			165,725			162,354
Regulatory Assets	100,598			104,971			111,274			117,240
Prepayments and Other Current Assets	4,271			24,302			9,423			28,908
Total Current Assets	419,071			449,107			420,946			442,787

Property, Plant and Equipment, Net	2,973,057			2,855,363			3,076,608			3,039,313

Deferred Debits and Other Assets:
Regulatory Assets	252,609			257,873			243,643			245,525
Other Long-Term Assets	35,793			34,176			42,797			37,720
Total Deferred Debits and Other Assets	288,402			292,049			286,440			283,245

Total Assets	$	3,680,530		$	3,596,519		$	3,783,994		$	3,765,345

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	107,500		$	231,300		$	144,900		$	160,900
Long-Term Debt - Current Portion	70,000			—
Long-Term Debt – Current Portion							70,000			70,000
Accounts Payable	76,762			87,925			70,710			85,716
Accounts Payable to Affiliated Companies	34,350			24,214			40,463			29,154
Regulatory Liabilities	5,519			6,898			17,224			12,659
Other Current Liabilities	48,339			43,921			52,771			43,253
Total Current Liabilities	342,470			394,258			396,068			401,682

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	774,737			705,894			796,118			785,385
Regulatory Liabilities	46,428			47,851			45,600			44,779
Accrued Pension, SERP and PBOP	84,547			89,579			91,911			94,652
Other Long-Term Liabilities	50,249			50,746			48,435			49,442
Total Deferred Credits and Other Liabilities	955,961			894,070			982,064			974,258

Capitalization:
Long-Term Debt	1,001,790			1,071,017			1,002,305			1,002,048

Common Stockholder’s Equity:
Common Stockholder's Equity:
Common Stock	—			—			—			—
Capital Surplus, Paid In	843,134			748,634			843,134			843,134
Retained Earnings	542,530			494,901			565,098			549,286
Accumulated Other Comprehensive Loss	(5,355		)	(6,361		)	(4,675		)	(5,063		)
Common Stockholder’s Equity	1,380,309			1,237,174
Common Stockholder's Equity							1,403,557			1,387,357
Total Capitalization	2,382,099			2,308,191			2,405,862			2,389,405

Total Liabilities and Capitalization	$	3,680,530		$	3,596,519		$	3,783,994		$	3,765,345

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

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,				For the Nine Months Ended September 30,				For the Three Months Ended March 31,
(Thousands of Dollars)	2016		2015		2016		2015		2017		2016

Operating Revenues	$	266,946	$	234,364	$	727,753	$	761,086	$	253,157	$	242,290

Operating Expenses:
Purchased Power, Fuel and Transmission	59,833		53,017		155,700		200,533		61,747		50,214
Operations and Maintenance	64,183		65,190		187,184		200,085		62,351		59,213
Depreciation	29,646		26,592		86,524		77,989		30,735		28,235
Amortization of Regulatory Assets, Net	14,158		1,967		14,490		29,148		5,445		8,518
Energy Efficiency Programs	3,983		3,873		10,862		11,001		3,746		3,620
Taxes Other Than Income Taxes	20,460		20,104		64,543		61,435		20,881		21,795
Total Operating Expenses	192,263		170,743		519,303		580,191		184,905		171,595
Operating Income	74,683		63,621		208,450		180,895		68,252		70,695
Interest Expense	12,397		11,647		37,386		34,582		12,808		12,461
Other Income, Net	574		685		1,007		2,313		1,198		150
Income Before Income Tax Expense	62,860		52,659		172,071		148,626		56,642		58,384
Income Tax Expense	24,345		20,158		66,242		56,135		22,330		22,326
Net Income	$	38,515	$	32,501	$	105,829	$	92,491	$	34,312	$	36,058

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

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended September 30,					For the Nine Months Ended September 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	2016		2015			2016		2015			2017		2016

Net Income	$	38,515	$	32,501		$	105,829	$	92,491		$	34,312	$	36,058
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	290		291			871		872			291		290
Changes in Unrealized Gains/(Losses) on Marketable Securities	56		(169		)	135		(236		)
Changes in Unrealized Gains on Marketable Securities											97		16
Other Comprehensive Income, Net of Tax	346		122			1,006		636			388		306
Comprehensive Income	$	38,861	$	32,623		$	106,835	$	93,127		$	34,700	$	36,364

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

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Three Months Ended March 31,
(Thousands of Dollars)	2016			2015			2017			2016

Operating Activities:
Net Income	$	105,829		$	92,491		$	34,312		$	36,058
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	86,524			77,989			30,735			28,235
Deferred Income Taxes	74,522			42,563			11,290			21,181
Regulatory (Under)/Over Recoveries, Net	(4,289		)	2,639
Regulatory Over/(Under) Recoveries, Net							3,507			(2,291		)
Amortization of Regulatory Assets, Net	14,490			29,148			5,445			8,518
Other	(12,660		)	10,894			(4,471		)	(9,166		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(28,754		)	(25,126		)	1,149			(17,207		)
Fuel, Materials, Supplies and Inventory	(4,014		)	4,156			(3,371		)	6,903
Taxes Receivable/Accrued, Net	33,589			9,026			1,778			57,935
Accounts Payable	14,508			(20,058		)	5,475			2,100
Other Current Assets and Liabilities, Net	26,207			20,141			27,332			24,021
Net Cash Flows Provided by Operating Activities	305,952			243,863			113,181			156,287

Investing Activities:
Investments in Property, Plant and Equipment	(215,804		)	(209,522		)	(75,327		)	(72,338		)
Other Investing Activities	272			241			(145		)	84
Net Cash Flows Used in Investing Activities	(215,532		)	(209,281		)	(75,472		)	(72,254		)

Financing Activities:
Cash Dividends on Common Stock	(58,200		)	(79,500		)	(18,500		)	(19,400		)
Capital Contributions from Eversource Parent	94,500			—			—			11,500
(Decrease)/Increase in Notes Payable to Eversource Parent	(123,800		)	46,800
Decrease in Notes Payable to Eversource Parent							(16,000		)	(74,200		)
Other Financing Activities	(217		)	(268		)	(112		)	(86		)
Net Cash Flows Used in Financing Activities	(87,717		)	(32,968		)	(34,612		)	(82,186		)
Net Increase in Cash	2,703			1,614			3,097			1,847
Cash - Beginning of Period	1,733			489			4,646			1,733
Cash - End of Period	$	4,436		$	2,103		$	7,743		$	3,580

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

WESTERN MASSACHUSETTS ELECTRIC COMPANY

CONDENSED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	September 30, 2016			December 31, 2015			As of March 31, 2017			As of December 31, 2016

ASSETS
Current Assets:
Cash	$	—		$	834		$	769		$	—
Receivables, Net	59,685			50,912			57,340			54,940
Accounts Receivable from Affiliated Companies	11,962			18,633			16,588			14,425
Unbilled Revenues	12,169			15,065			16,850			15,329
Taxes Receivable	1			33,407
Materials, Supplies and Inventory	8,068			5,992			9,911			8,618
Regulatory Assets	54,081			56,166			66,033			64,123
Prepayments and Other Current Assets	1,374			1,890			3,365			2,595
Total Current Assets	147,340			182,899			170,856			160,030

Property, Plant and Equipment, Net	1,643,335			1,575,306			1,694,818			1,678,262

Deferred Debits and Other Assets:
Regulatory Assets	128,308			135,010			123,317			127,291
Other Long-Term Assets	28,165			24,875			31,171			29,062
Total Deferred Debits and Other Assets	156,473			159,885			154,488			156,353

Total Assets	$	1,947,148		$	1,918,090		$	2,020,162		$	1,994,645

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	48,200		$	143,400		$	71,400		$	51,000
Accounts Payable	38,191			58,364			44,023			56,036
Accounts Payable to Affiliated Companies	14,501			19,896			14,837			19,478
Obligations to Third Party Suppliers	11,444			9,654			9,705			10,508
Renewable Portfolio Standards Compliance Obligations	16,314			6,395			25,110			20,383
Regulatory Liabilities	12,384			13,122			12,897			14,888
Other Current Liabilities	12,258			13,878			7,659			14,984
Total Current Liabilities	153,292			264,709			185,631			187,277

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	486,137			470,539			507,203			490,793
Regulatory Liabilities	14,422			11,597			19,119			17,227
Accrued Pension, SERP and PBOP	16,032			19,515			18,660			20,390
Other Long-Term Liabilities	42,072			36,819			44,177			41,308
Total Deferred Credits and Other Liabilities	558,663			538,470			589,159			569,718

Capitalization:
Long-Term Debt	566,657			517,329			566,415			566,536

Common Stockholder’s Equity:
Common Stockholder's Equity:
Common Stock	10,866			10,866			10,866			10,866
Capital Surplus, Paid In	444,399			391,398			444,398			444,398
Retained Earnings	215,743			198,140			225,930			218,212
Accumulated Other Comprehensive Loss	(2,472		)	(2,822		)	(2,237		)	(2,362		)
Common Stockholder’s Equity	668,536			597,582
Common Stockholder's Equity							678,957			671,114
Total Capitalization	1,235,193			1,114,911			1,245,372			1,237,650

Total Liabilities and Capitalization	$	1,947,148		$	1,918,090		$	2,020,162		$	1,994,645

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

WESTERN MASSACHUSETTS ELECTRIC COMPANY

CONDENSED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,				For the Nine Months Ended September 30,				For the Three Months Ended March 31,
(Thousands of Dollars)	2016		2015		2016		2015		2017			2016

Operating Revenues	$	124,042	$	125,093	$	368,533	$	403,151	$	130,136		$	128,095

Operating Expenses:
Purchased Power and Transmission	32,178		36,465		104,406		149,182		40,867			39,563
Operations and Maintenance	24,125		21,762		68,018		61,651		22,498			21,805
Depreciation	11,567		11,196		34,414		32,420		12,002			11,371
Amortization of Regulatory Assets, Net	1,102		3,930		3,305		11,194
Amortization of Regulatory (Liabilities)/Assets, Net									(488		)	1,212
Energy Efficiency Programs	12,389		12,107		33,593		32,701		10,664			10,856
Taxes Other Than Income Taxes	10,609		9,599		30,440		28,430		10,428			10,232
Total Operating Expenses	91,970		95,059		274,176		315,578		95,971			95,039
Operating Income	32,072		30,034		94,357		87,573		34,165			33,056
Interest Expense	6,222		5,901		18,298		19,014		6,249			6,004
Other Income, Net	179		587		133		2,406
Other Income/(Loss), Net									77			(149		)
Income Before Income Tax Expense	26,029		24,720		76,192		70,965		27,993			26,903
Income Tax Expense	10,018		9,749		30,089		28,555		10,775			10,076
Net Income	$	16,011	$	14,971	$	46,103	$	42,410	$	17,218		$	16,827

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

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended September 30,					For the Nine Months Ended September 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	2016		2015			2016		2015			2017		2016

Net Income	$	16,011	$	14,971		$	46,103	$	42,410		$	17,218	$	16,827
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	109		101			328		270			109		109
Changes in Unrealized Gains/(Losses) on Marketable Securities	9		(27		)	22		(38		)
Changes in Unrealized Gains on Marketable Securities											16		3
Other Comprehensive Income, Net of Tax	118		74			350		232			125		112
Comprehensive Income	$	16,129	$	15,045		$	46,453	$	42,642		$	17,343	$	16,939

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

WESTERN MASSACHUSETTS ELECTRIC COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Three Months Ended March 31,
(Thousands of Dollars)	2016			2015			2017			2016

Operating Activities:
Net Income	$	46,103		$	42,410		$	17,218		$	16,827
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	34,414			32,420			12,002			11,371
Deferred Income Taxes	15,587			5,531			16,176			9,921
Regulatory Overrecoveries, Net	323			4,024
Amortization of Regulatory Assets, Net	3,305			11,194
Regulatory Underrecoveries, Net							(452		)	(6,100		)
Amortization of Regulatory (Liabilities)/Assets, Net							(488		)	1,212
Other	(2,532		)	(4,500		)	(326		)	(541		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	1,933			(32,664		)	(5,924		)	2,197
Taxes Receivable/Accrued, Net	36,658			24,064			(1,404		)	26,976
Accounts Payable	(16,240		)	(14,018		)	(10,141		)	(11,011		)
Other Current Assets and Liabilities, Net	5,277			(463		)	(4,057		)	(136		)
Net Cash Flows Provided by Operating Activities	124,828			67,998			22,604			50,716

Investing Activities:
Investments in Property, Plant and Equipment	(104,811		)	(93,705		)	(32,744		)	(39,891		)
Proceeds from Sales of Marketable Securities	1,934			71,110
Purchases of Marketable Securities	(1,894		)	(71,625		)
Other Investing Activities							9			13
Net Cash Flows Used in Investing Activities	(104,771		)	(94,220		)	(32,735		)	(39,878		)

Financing Activities:
Cash Dividends on Common Stock	(28,500		)	(27,900		)	(9,500		)	(9,500		)
Capital Contribution from Eversource Parent	53,000			—
(Decrease)/Increase in Notes Payable to Eversource Parent	(95,200		)	104,800
Issuance/(Retirement) of Long-Term Debt	50,000			(50,000		)
Increase in Notes Payable to Eversource Parent							20,400			100
Other Financing Activities	(191		)	(20		)	—			(3		)
Net Cash Flows (Used in)/Provided by Financing Activities	(20,891		)	26,880
Net (Decrease)/Increase in Cash	(834		)	658
Net Cash Flows Provided by/(Used in) Financing Activities							10,900			(9,403		)
Net Increase in Cash							769			1,435
Cash - Beginning of Period	834			—			—			834
Cash - End of Period	$	—		$	658		$	769		$	2,269

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

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 CONDENSED FINANCIAL STATEMENTS (Unaudited)

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

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

A. Basis of Presentation

Eversource Energy is a public utility holding company primarily engaged, through its ~~wholly owned~~wholly-owned regulated utility subsidiaries, in the energy delivery business. Eversource ~~Energy’s wholly owned~~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~~3.7 million electric and natural gas customers through these six regulated utilities in Connecticut, Massachusetts and New Hampshire.

The unaudited condensed 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 unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P and WMECO are herein collectively referred to as the ~~“financial~~"financial statements.”"

The combined notes to the financial statements have been prepared pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures included in annual financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations. The accompanying financial statements should be read in conjunction with the Combined Notes to Financial Statements included in Item 8, ~~“Financial~~"Financial Statements and Supplementary Data,”" of the Eversource ~~2015~~2016 Form 10-K, which was filed with the SEC. 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.

The financial statements contain, in the opinion of management, all adjustments (including normal, recurring adjustments) necessary to present fairly ~~Eversource’s,~~Eversource's, CL~~&P’s,~~&P's, NSTAR ~~Electric’s, PSNH’s~~Electric's, PSNH's and ~~WMECO’s~~WMECO's financial position as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, and the results of operations, ~~and~~ comprehensive income ~~for the three~~ and ~~nine months ended September 30, 2016 and 2015, and the~~ cash flows for the ~~nine~~three months ended ~~September 30, 2016~~March 31, 2017 and ~~2015.~~2016. The results of operations, ~~and~~ comprehensive income ~~for the three~~ and ~~nine months ended September 30, 2016 and 2015 and the~~ cash flows for the ~~nine~~three months ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~ are not necessarily indicative of the results expected for a full year.

Eversource consolidates CYAPC and YAEC because CL~~&P’s,~~&P's, NSTAR ~~Electric’s, PSNH’s~~Electric's, PSNH's and ~~WMECO’s~~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.

Access Northeast is a natural gas pipeline and storage project (the Project) being developed jointly by Eversource, Spectra Energy Partners, LP (Spectra), and National Grid plc (National Grid) through Algonquin Gas Transmission, LLC (AGT). The Project 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 natural gas pipeline. Eversource and Spectra 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 facilities will be funded in proportion to the respective ownership interest. Eversource’s cumulative equity investment in the Project as of September 30, 2016 of $28.6 million is presented in Other Long-Term Assets.

~~Eversource’s~~Eversource's utility ~~subsidiaries’~~subsidiaries' distribution (including ~~generation)~~generation assets) 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~~"Regulatory Accounting,”" for further information.

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

presentation.

B. Accounting Standards

Accounting Standards Issued but ~~not~~Not Yet Effective: In May 2014, the Financial Accounting Standards Board ~~(FASB)~~("FASB") issued an Accounting Standards Update ~~(ASU) 2014-9,~~("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 2014-9 to the first quarter of 2018, with 2017 application permitted. The guidance continues to be interpreted on an industry specific level.~~ The Company is evaluating the requirements and potential impacts of ASU ~~2014-9~~2014-09 and will implement the standard in the first quarter of ~~2018.~~2018 cumulatively at the date of initial application. The guidance continues to be interpreted on an industry specific level, including the timing of recognizing revenues from billings to protected customers that may not meet the collectability threshold for revenue recognition. Therefore, while the effects of implementing the ASU ison results of operations are not ~~currently~~ expected to ~~have a~~be material, ~~impact~~there may be changes in the timing of revenue recognition on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH orand WMECO.

In January 2016, the FASB issued ASU ~~2016-1,~~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 accumulated other comprehensive income within ~~shareholders’~~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 ~~September 30, 2016~~March 31, 2017 was approximately ~~$50~~$49 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 orand WMECO.

In February 2016, the FASB issued ASU ~~2016-2,~~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 ~~2016-2,~~2016-02, including balance sheet recognition of leases previously deemed operating leases, and expects to implement the ASU in the first quarter of 2019.

~~Recently Adopted Accounting Standards:~~ In March ~~2016,~~2017, the FASB issued ASU ~~2016-9,~~2017-07, Compensation ~~- Stock Compensation: Improvements~~– Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost, required to ~~Employee Share-Based Payment Accounting. The ASU is intended to simplify some aspects of the accounting for share-based payment transactions. The Company~~be implemented ~~this guidance~~ in the first quarter of ~~2016, as permitted by early adoption. Beginning in the first quarter~~2018. The ASU requires separate presentation of ~~2016, the excess tax benefits associated~~service cost from other components of net pension and PBOP costs, with the ~~distribution~~other components presented as non-operating income and not subject to capitalization. The Company is assessing the impacts of ~~stock compensation awards, previously recognized in Capital Surplus, Paid In within Common Shareholders’ Equity~~the ASU on the ~~balance sheet, are recognized in income tax expense in~~financial statements of Eversource, CL&P, NSTAR Electric, PSNH and WMECO, however implementation of the income statement. The implementation reduced income tax expense by $2.9 million for the nine months ended September 30, 2016. Also, beginning in 2016, in the statement of cash flows, the excess tax benefits are presented as an operating activity rather thanASU is not expected to have a financing activity, and in both periods presented, cash paid to satisfy the statutory income tax withholding obligation previously reflected within operating activities in 2015 is now treated as a financing activity. The cash payments to satisfy this obligation for the nine months ended September 30, 2016 and 2015 were $9.1 million and $9.7 million, respectively, and are included in Other Financing Activitiesmaterial impact on the ~~statements~~net income of ~~cash flows.~~ Eversource, CL&P, NSTAR Electric, PSNH and WMECO.

C. 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~~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 also to ~~also~~ recover in rates, amounts associated with certain uncollectible hardship accounts receivable. Certain of NSTAR ~~Electric’s~~Electric's uncollectible hardship accounts receivable are expected to be recovered in future rates, similar to WMECO and NSTAR Gas. These uncollectible customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets.

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


	Total Provision for Uncollectible Accounts				Uncollectible Hardship				Total Provision for Uncollectible Accounts				Uncollectible Hardship
(Millions of Dollars)	As of September 30, 2016		As of December 31, 2015		As of September 30, 2016		As of December 31, 2015		As of March 31, 2017		As of December 31, 2016		As of March 31, 2017		As of December 31, 2016
Eversource	$	208.1	$	190.7	$	126.5	$	118.5	$	203.2	$	200.6	$	118.0	$	119.9
CL&P	85.3		79.5		66.9		68.1		88.7		86.4		69.8		67.7
NSTAR Electric	59.9		52.6		30.3		25.3		52.6		54.8		23.7		26.2
PSNH	9.9		8.7		—		—		10.4		9.9		—		—
WMECO	16.8		14.0		10.7		7.4		14.2		15.5		8.2		9.9

D. Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as ~~“normal~~"normal purchases or normal ~~sales” (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~~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~~Eversource's fair value measurements are described in Note 4, ~~“Derivative~~"Derivative Instruments,”" Note 5, ~~“Marketable~~"Marketable Securities,”" and Note 10, ~~“Fair~~"Fair Value of Financial Instruments,”" to the financial statements.

E. 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~~income/(loss) related to equity method ~~investees.~~investments. Investment income/(loss) primarily relates to debt and equity securities held in trust. For further information, see Note 5, ~~“Marketable~~"Marketable Securities,”" to the financial statements.

F. 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:


	For the Three Months Ended				For the Nine Months Ended				For the Three Months Ended
(Millions of Dollars)	September 30, 2016		September 30, 2015		September 30, 2016		September 30, 2015		March 31, 2017		March 31, 2016
Eversource	$	45.1	$	37.8	$	124.8	$	112.9	$	42.2	$	42.2
CL&P	42.6		35.5		112.2		98.0		33.9		36.0

As agents for state and local governments, ~~Eversource’s~~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.

G. Supplemental Cash Flow Information

Non-cash investing activities include plant additions included in Accounts Payable as follows:


(Millions of Dollars)	As of September 30, 2016		As of September 30, 2015		As of March 31, 2017		As of March 31, 2016
Eversource	$	203.6	$	160.7	$	220.5	$	125.6
CL&P	64.5		46.0		104.2		52.6
NSTAR Electric	39.4		31.2		29.8		11.7
PSNH	31.0		33.8		28.7		26.8
WMECO	17.6		15.5		19.6		10.7

2. REGULATORY ACCOUNTING

~~Eversource’s~~Eversource's Regulated companies are subject to ~~rate-regulation~~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’~~companies' financial statements reflect the effects of the rate-making process. The rates charged to the customers of ~~Eversource’s~~Eversource's Regulated companies are designed to collect each ~~company’s~~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~~its respective investments in long-lived assets, including regulatory assets. If management were to determine that it could no longer apply the accounting guidance applicable to rate-regulated enterprises to any of the Regulated ~~companies’~~companies' operations, or if management could not conclude it is probable that costs would be recovered from customers in future rates, the costs would be charged to net income in the period in which the determination is made.

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


	As of September 30, 2016		As of December 31, 2015
Eversource					As of March 31, 2017		As of December 31, 2016
(Millions of Dollars)	Eversource		Eversource
Benefit Costs	$	1,618.7	$	1,828.2	$	1,782.5	$	1,817.8
Derivative Liabilities	443.7		388.0		416.3		423.3
Income Taxes, Net	641.7		650.9		645.4		644.5
Storm Restoration Costs	407.7		436.9		375.8		385.3
Goodwill-related	469.5		484.9		459.3		464.4
Regulatory Tracker Mechanisms	454.1		526.5		578.9		576.6
Contractual Obligations - Yankee Companies	66.0		134.4		70.6		84.9
Other Regulatory Assets	120.9		134.0		110.9		129.5
Total Regulatory Assets	4,222.3		4,583.8		4,439.7		4,526.3
Less: Current Portion	752.4		845.8		875.0		887.6
Total Long-Term Regulatory Assets	$	3,469.9	$	3,738.0	$	3,564.7	$	3,638.7


	As of September 30, 2016								As of December 31, 2015								As of March 31, 2017								As of December 31, 2016
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		WMECO		CL&P		NSTAR Electric		PSNH		WMECO		CL&P		NSTAR Electric		PSNH		WMECO		CL&P		NSTAR Electric		PSNH		WMECO
Benefit Costs	$	407.1	$	414.6	$	174.7	$	82.1	$	413.6	$	479.9	$	164.2	$	84.9	$	421.5	$	429.9	$	181.1	$	85.1	$	429.3	$	438.6	$	184.2	$	86.7
Derivative Liabilities	441.0		2.7		—		—		380.8		1.3		—		—		413.5		2.5		—		—		420.5		2.8		—		—
Income Taxes, Net	438.5		88.3		27.0		31.2		444.4		85.7		34.5		31.8		435.9		90.4		23.4		30.9		437.0		89.7		24.2		30.8
Storm Restoration Costs	253.7		115.1		20.8		18.1		271.4		110.9		31.5		23.1		225.1		118.5		17.0		15.2		239.8		112.5		17.1		15.9
Goodwill-related	—		403.1		—		—		—		416.3		—		—		—		394.3		—		—		—		398.7		—		—
Regulatory Tracker Mechanisms	50.6		230.4		99.9		37.8		45.1		311.0		101.2		40.1		170.5		245.9		101.8		49.1		123.9		257.3		104.5		46.7
Other Regulatory Assets	75.4		48.2		30.8		13.2		82.0		56.3		31.5		11.3		71.1		46.1		31.6		9.0		76.6		47.5		32.7		11.3
Total Regulatory Assets	1,666.3		1,302.4		353.2		182.4		1,637.3		1,461.4		362.9		191.2		1,737.6		1,327.6		354.9		189.3		1,727.1		1,347.1		362.7		191.4
Less: Current Portion	267.7		259.2		100.6		54.1		268.3		348.4		105.0		56.2		370.1		276.5		111.3		66.0		335.5		289.4		117.2		64.1
Total Long-Term Regulatory Assets	$	1,398.6	$	1,043.2	$	252.6	$	128.3	$	1,369.0	$	1,113.0	$	257.9	$	135.0	$	1,367.5	$	1,051.1	$	243.6	$	123.3	$	1,391.6	$	1,057.7	$	245.5	$	127.3

Regulatory Costs in Other Long-Term Assets: ~~The~~Eversource's Regulated companies had ~~$87.9~~$91.4 million (including ~~$4.0~~$5.0 million for CL&P, ~~$40.2~~$33.3 million for NSTAR Electric, ~~$6.1~~$12.9 million for PSNH and ~~$20.1~~$22.1 million for WMECO) and ~~$75.3~~$86.3 million (including ~~$3.1~~$5.9 million for CL&P, ~~$35.4~~$35.0 million for NSTAR Electric, ~~$4.8~~$8.2 million for PSNH, and ~~$16.7~~$20.1 million for WMECO) of additional regulatory costs as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, 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.

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


	As of September 30, 2016		As of December 31, 2015
Eversource					As of March 31, 2017		As of December 31, 2016
(Millions of Dollars)	Eversource		Eversource
Cost of Removal	$	457.7	$	437.1	$	469.6	$	459.7
Benefit Costs					130.8		136.2
Regulatory Tracker Mechanisms	153.4		99.7		188.8		145.3
AFUDC - Transmission	65.8		66.1		65.8		65.8
Other Regulatory Liabilities	33.7		18.5		37.2		42.1
Total Regulatory Liabilities	710.6		621.4		892.2		849.1
Less: Current Portion	160.4		107.8		199.2		146.8
Total Long-Term Regulatory Liabilities	$	550.2	$	513.6	$	693.0	$	702.3


	As of September 30, 2016								As of December 31, 2015								As of March 31, 2017								As of December 31, 2016
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		WMECO		CL&P		NSTAR Electric		PSNH		WMECO		CL&P		NSTAR Electric		PSNH		WMECO		CL&P		NSTAR Electric		PSNH		WMECO
Cost of Removal	$	39.7	$	269.5	$	45.8	$	5.8	$	24.1	$	257.4	$	47.2	$	2.8	$	42.5	$	273.3	$	44.8	$	10.6	$	38.8	$	271.6	$	44.1	$	8.6
Benefit Costs	—		81.7		—		—		—		—		—		—		—		109.8		—		—		—		113.1		—		—
Regulatory Tracker Mechanisms	62.2		48.4		2.6		12.2		56.2		3.3		3.4		12.9		44.5		62.2		15.0		12.7		37.2		63.7		10.7		14.7
AFUDC - Transmission	50.6		6.4		—		8.8		51.5		5.7		—		8.9		49.9		7.2		—		8.7		50.2		6.9		—		8.7
Other Regulatory Liabilities	12.8		—		3.5		—		4.2		1.3		4.2		0.1		23.2		0.2		3.0		—		21.0		0.2		2.7		0.1
Total Regulatory Liabilities	165.3		406.0		51.9		26.8		136.0		267.7		54.8		24.7		160.1		452.7		62.8		32.0		147.2		455.5		57.5		32.1
Less: Current Portion	75.7		48.8		5.5		12.4		61.2		3.3		6.9		13.1		58.9		62.2		17.2		12.9		47.1		63.7		12.7		14.9
Total Long-Term Regulatory Liabilities	$	89.6	$	357.2	$	46.4	$	14.4	$	74.8	$	264.4	$	47.9	$	11.6	$	101.2	$	390.5	$	45.6	$	19.1	$	100.1	$	391.8	$	44.8	$	17.2

3. PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

The following tables summarize ~~the investments in~~ utility property, plant and equipment by asset category:


	As of September 30, 2016			As of December 31, 2015
Eversource							As of March 31, 2017			As of December 31, 2016
(Millions of Dollars)	Eversource			Eversource
Distribution - Electric	$	13,536.1		$	13,054.8		$	13,893.9		$	13,716.9
Distribution - Natural Gas	2,865.8			2,727.2			3,049.3			3,010.4
Transmission - Electric	8,033.0			7,691.9			8,600.1			8,517.4
Generation	1,218.9			1,194.1			1,225.6			1,224.2
Electric and Natural Gas Utility	25,653.8			24,668.0			26,768.9			26,468.9
Other ⁽¹⁾	635.3			558.6			585.1			591.6
Property, Plant and Equipment, Gross	26,289.1			25,226.6			27,354.0			27,060.5
Less: Accumulated Depreciation
Electric and Natural Gas Utility	(6,442.3		)	(6,141.1		)	(6,607.5		)	(6,480.4		)
Other	(285.8		)	(255.6		)	(251.3		)	(242.0		)
Total Accumulated Depreciation	(6,728.1		)	(6,396.7		)	(6,858.8		)	(6,722.4		)
Property, Plant and Equipment, Net	19,561.0			18,829.9			20,495.2			20,338.1
Construction Work in Progress	1,246.9			1,062.5			1,146.7			1,012.4
Total Property, Plant and Equipment, Net	$	20,807.9		$	19,892.4		$	21,641.9		$	21,350.5

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


	As of September 30, 2016												As of December 31, 2015												As of March 31, 2017												As of December 31, 2016
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH			WMECO
Distribution	$	5,513.9		$	5,309.2		$	1,918.3		$	834.6		$	5,377.2		$	5,100.5		$	1,804.8		$	812.3		$	5,628.7		$	5,471.5		$	1,981.9		$	851.8		$	5,562.9		$	5,402.3		$	1,949.8		$	841.9
Transmission	3,752.7			2,211.7			1,005.5			1,014.9			3,618.0			2,131.3			928.2			964.9			3,930.1			2,462.8			1,075.5			1,083.4			3,912.9			2,435.8			1,059.3			1,061.1
Generation	—			—			1,182.9			36.0			—			—			1,158.1			36.0			—			—			1,189.6			36.0			—			—			1,188.2			36.0
Property, Plant and Equipment, Gross	9,266.6			7,520.9			4,106.7			1,885.5			8,995.2			7,231.8			3,891.1			1,813.2			9,558.8			7,934.3			4,247.0			1,971.2			9,475.8			7,838.1			4,197.3			1,939.0
Less: Accumulated Depreciation	(2,102.3		)	(1,996.8		)	(1,243.8		)	(330.6		)	(2,041.9		)	(1,886.8		)	(1,171.0		)	(307.0		)	(2,125.4		)	(2,064.4		)	(1,277.7		)	(347.0		)	(2,082.4		)	(2,025.4		)	(1,254.7		)	(338.8		)
Property, Plant and Equipment, Net	7,164.3			5,524.1			2,862.9			1,554.9			6,953.3			5,345.0			2,720.1			1,506.2			7,433.4			5,869.9			2,969.3			1,624.2			7,393.4			5,812.7			2,942.6			1,600.2
Construction Work in Progress	288.9			351.8			110.2			88.4			203.5			310.5			135.3			69.1			321.5			239.0			107.3			70.6			239.0			239.1			96.7			78.1
Total Property, Plant and Equipment, Net	$	7,453.2		$	5,875.9		$	2,973.1		$	1,643.3		$	7,156.8		$	5,655.5		$	2,855.4		$	1,575.3		$	7,754.9		$	6,108.9		$	3,076.6		$	1,694.8		$	7,632.4		$	6,051.8		$	3,039.3		$	1,678.3

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~~non-derivative contracts.

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

Derivative contracts that are not designated as normal are recorded at fair value as current or long-term Derivative Assets or Derivative Liabilities on the balance sheets. For the 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:


	As of September 30, 2016									As of December 31, 2015									As of March 31, 2017									As of December 31, 2016
(Millions of Dollars)	Commodity Supply and Price Risk Management			Netting ⁽¹⁾			Net Amount Recorded as a Derivative			Commodity Supply and Price Risk Management			Netting ⁽¹⁾			Net Amount Recorded as a Derivative			Commodity Supply and Price Risk Management			Netting ⁽¹⁾			Net Amount Recorded as a Derivative			Commodity Supply and Price Risk Management			Netting ⁽¹⁾			Net Amount Recorded as a Derivative
Current Derivative Assets:
Level 2:
Eversource	$	2.6		$	(0.2	)	$	2.4		$	—		$	—		$	—		$	0.6		$	—		$	0.6		$	6.0		$	—		$	6.0
Level 3:
Eversource, CL&P																			12.5			(8.6		)	3.9			13.9			(9.4		)	4.5
Long-Term Derivative Assets:
Level 2:
Eversource																			$	—		$	—		$	—		$	0.3		$	(0.1	)	$	0.2
Level 3:
Eversource, CL&P																			78.3			(9.8		)	68.5			77.3			(11.7		)	65.6
Current Derivative Liabilities:
Level 3:
Eversource	15.7			(10.4		)	5.3			16.7			(10.9		)	5.8			$	(72.9	)	$	—		$	(72.9	)	$	(79.7	)	$	—		$	(79.7	)
CL&P	15.3			(10.4		)	4.9			16.7			(10.9		)	5.8			(70.7		)	—			(70.7		)	(77.8		)	—			(77.8		)
NSTAR Electric	0.4			—			0.4			—			—			—			(2.2		)	—			(2.2		)	(1.9		)	—			(1.9		)
Long-Term Derivative Assets:
Long-Term Derivative Liabilities:
Level 2:
Eversource	$	—		$	—		$	—		$	0.1		$	—		$	0.1		$	(0.3	)	$	—		$	(0.3	)	$	—		$	—		$	—
Level 3:
Eversource	79.3			(13.8		)	65.5			62.0			(19.3		)	42.7			(415.5		)	—			(415.5		)	(413.7		)	—			(413.7		)
CL&P	79.3			(13.8		)	65.5			60.7			(19.3		)	41.4			(415.2		)	—			(415.2		)	(412.8		)	—			(412.8		)
NSTAR Electric	—			—			—			1.3			—			1.3			(0.3		)	—			(0.3		)	(0.9		)	—			(0.9		)
Current Derivative Liabilities:
Level 2:
Eversource	$	—		$	—		$	—		$	(5.8	)	$	—		$	(5.8	)
Level 3:
Eversource	(87.1		)	—			(87.1		)	(92.3		)	—			(92.3		)
CL&P	(85.3		)	—			(85.3		)	(91.8		)	—			(91.8		)
NSTAR Electric	(1.8		)	—			(1.8		)	(0.5		)	—			(0.5		)
Long-Term Derivative Liabilities:
Level 3:
Eversource	$	(427.4	)	$	—		$	(427.4	)	$	(337.1	)	$	—		$	(337.1	)
CL&P	(426.1		)	—			(426.1		)	(336.2		)	—			(336.2		)
NSTAR Electric	(1.3		)	—			(1.3		)	(0.9		)	—			(0.9		)


⁽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.

For further information on the fair value of derivative contracts, see Note 1D, ~~“Summary~~"Summary of Significant Accounting Policies - Fair Value Measurements,”" to the financial statements.

Derivative Contracts at Fair Value with Offsetting Regulatory Amounts

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

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 ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, Eversource had ~~NYMEX~~New York Mercantile Exchange ("NYMEX") financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately ~~10.2~~5.4 million and ~~9.1~~9.2 million MMBtu of natural gas, respectively.

For the three months ended ~~September 30,~~March 31, 2017 and 2016, ~~and 2015,~~ there were losses of ~~$53.4~~$26.5 million and ~~$8.8~~$30.5 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with ~~Eversource’s~~Eversource's derivative contracts. ~~For the nine months ended September 30, 2016 and 2015, these losses were $127.8 million and $58.9 million, respectively.~~

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~~term of the contract.

Valuations of derivative contracts using a discounted cash flow methodology include assumptions regarding the timing and likelihood of scheduled payments and also reflect non-performance risk, including credit, using the default probability approach based on the ~~counterparty’s~~counterparty's credit rating for assets and the ~~Company’s~~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,~~Eversource's, including CL~~&P’s~~&P's and NSTAR ~~Electric’s,~~Electric's, Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts:


	As of September 30, 2016						As of December 31, 2015						As of March 31, 2017						As of December 31, 2016
	Range					Period Covered	Range					Period Covered	Range					Period Covered	Range					Period Covered
Capacity Prices:
Eversource	$	5.50	—	9.75	per kW-Month	2020 - 2026	$	10.81	—	15.82	per kW-Month	2016 - 2026
CL&P	$	5.50	—	9.75	per kW-Month	2020 - 2026	$	10.81	—	12.60	per kW-Month	2019 - 2026

Eversource, CL&P													$	5.00	—	8.70	per kW-Month	2020 - 2026	$	5.50	—	8.70	per kW-Month	2020 - 2026
Forward Reserve:
Eversource, CL&P	$	1.40	—	2.00	per kW-Month	2016 - 2024	$2.00				per kW-Month	2016 - 2024	$	1.40	—	2.00	per kW-Month	2017 - 2024	$	1.40	—	2.00	per kW-Month	2017 - 2024

REC Prices:
Eversource, NSTAR Electric	$	29	—	37	per REC	2016 - 2018	$	45	—	51	per REC	2016 - 2018	$	27.00	—	30.00	per REC	2017 - 2018	$	24.00	—	29.00	per REC	2017 - 2018

Exit price premiums of 42 percent through 2119 percent are also applied on these contracts and reflect the uncertainty and ~~liquidity~~illiquidity premiums that would be required based on the most recent market activity available for similar type contracts.

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.

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.


	For the Three Months Ended September 30,																		For the Three Months Ended March 31,
	2016									2015									2017									2016
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			Eversource			CL&P			NSTAR Electric			Eversource			CL&P			NSTAR Electric			Eversource			CL&P			NSTAR Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(412.6	)	$	(411.3	)	$	(1.3	)	$	(422.4	)	$	(420.2	)	$	(2.2	)	$	(423.3	)	$	(420.5	)	$	(2.8	)	$	(380.9	)	$	(380.8	)	$	(0.1	)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities	(52.3		)	(49.8		)	(2.5		)	(6.0		)	(7.6		)	1.6
Net Realized/Unrealized Losses Included in Regulatory Assets and Liabilities																			(15.4		)	(14.6		)	(0.8		)	(28.9		)	(24.6		)	(4.3		)
Settlements	21.2			20.1			1.1			21.4			20.9			0.5			22.7			21.6			1.1			22.1			20.3			1.8
Fair Value as of End of Period	$	(443.7	)	$	(441.0	)	$	(2.7	)	$	(407.0	)	$	(406.9	)	$	(0.1	)	$	(416.0	)	$	(413.5	)	$	(2.5	)	$	(387.7	)	$	(385.1	)	$	(2.6	)

	For the Nine Months Ended September 30,
	2016									2015
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			Eversource			CL&P			NSTAR Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(380.9	)	$	(380.8	)	$	(0.1	)	$	(415.4	)	$	(410.9	)	$	(4.5	)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities	(128.9		)	(122.0		)	(6.9		)	(55.3		)	(56.6		)	1.3
Settlements	66.1			61.8			4.3			63.7			60.6			3.1
Fair Value as of End of Period	$	(443.7	)	$	(441.0	)	$	(2.7	)	$	(407.0	)	$	(406.9	)	$	(0.1	)

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.

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 ~~September 30, 2016 and~~ December 31, ~~2015,~~2016, these securities were classified as Level 1 in the fair value hierarchy and totaled ~~$10.3 million~~$9.6 million. These securities were sold during the first quarter of 2017 and ~~$14.2 million, respectively.~~were no longer held as of March 31, 2017. For the three months ended ~~September 30,~~March 31, 2016, ~~and 2015,~~ net gains on these securities of ~~$0.1~~$0.2 million ~~and net losses of $0.5 million, respectively, and for the nine months ended September 30, 2016 and 2015, net gains of $0.6 million and $1.6 million, respectively,~~ were recorded in Other Income, Net on the ~~statements~~statement of income. Dividend income is recorded in Other Income, Net when dividends are declared.

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


	As of September 30, 2016									As of December 31, 2015									As of March 31, 2017									As of December 31, 2016
Eversource (Millions of Dollars)	Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value
Debt Securities	$	261.2	$	10.7	$	—		$	271.9	$	256.5	$	4.5	$	(0.6	)	$	260.4	$	296.9	$	2.4	$	(1.3	)	$	298.0	$	296.2	$	1.1	$	(2.1	)	$	295.2
Equity Securities	206.7		63.7		(1.0		)	269.4		215.3		59.2		(3.4		)	271.1		201.9		77.8		(0.5		)	279.2		203.3		62.3		(1.2		)	264.4

~~Eversource’s~~Eversource's debt and equity securities include ~~CYAPC’s~~CYAPC's and ~~YAEC’s~~YAEC's marketable securities held in nuclear decommissioning trusts in the amounts of ~~$446.9~~$482.3 million and ~~$436.9~~$466.7 million as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, respectively. Unrealized gains and losses for these nuclear decommissioning trusts are recorded in Marketable Securities with the corresponding offset to Other Long-Term Liabilities on the balance sheets, with no impact on the statements of income.

Unrealized Losses and Other-than-Temporary Impairment: There have been no significant unrealized losses, other-than-temporary impairments or credit losses for the three ~~and nine~~ months ended ~~September 30, 2016~~March 31, 2017 and ~~2015.~~2016. Factors considered in determining whether a credit loss exists include the duration and severity of the impairment, adverse conditions specifically affecting the issuer, and the payment history, ratings and rating changes of the security. For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated.

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

Contractual Maturities: As of ~~September 30, 2016,~~March 31, 2017, the contractual maturities of available-for-sale debt securities were as follows:


Eversource (Millions of Dollars)	Amortized Cost		Fair Value		Amortized Cost		Fair Value
Less than one year⁽¹⁾	$	29.3	$	29.1	$	60.6	$	60.6
One to five years	58.0		59.1		47.4		48.1
Six to ten years	47.0		49.5		54.7		55.3
Greater than ten years	126.9		134.2		134.2		134.0
Total Debt Securities	$	261.2	$	271.9	$	296.9	$	298.0


⁽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:


Eversource (Millions of Dollars)	As of September 30, 2016		As of December 31, 2015		As of March 31, 2017		As of December 31, 2016
Level 1:
Mutual Funds and Equities	$	279.7	$	285.3	$	279.2	$	274.0
Money Market Funds	24.5		26.9		56.2		54.8
Total Level 1	$	304.2	$	312.2	$	335.4	$	328.8
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury)	$	65.5	$	46.6	$	57.0	$	63.0
Corporate Debt Securities	43.3		43.9		41.6		41.1
Asset-Backed Debt Securities	18.0		20.0		19.8		18.5
Municipal Bonds	110.3		111.4		112.5		107.5
Other Fixed Income Securities	10.3		11.6		10.9		10.3
Total Level 2	$	247.4	$	233.5	$	241.8	$	240.4
Total Marketable Securities	$	551.6	$	545.7	$	577.2	$	569.2

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. SHORT-TERM AND LONG-TERM DEBT

Commercial Paper Programs and Credit Agreements: Eversource parent has a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. As of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, Eversource parent had ~~$698.5~~$801.0 million and approximately ~~$1.1~~$1.0 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving ~~$751.5~~$649.0 million and ~~$351.5~~$428.0 million of available borrowing capacity as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, respectively. The weighted-average interest rate on these borrowings as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015~~2016 was ~~0.66~~1.12 percent and ~~0.72~~0.88 percent, respectively. As of ~~September 30,~~March 31, 2017, there were intercompany loans from Eversource parent of $3.4 million to CL&P, $144.9 million to PSNH, and $71.4 million to WMECO. As of December 31, 2016, there were intercompany loans from Eversource parent of ~~$108.5~~$80.1 million to CL&P, ~~$107.5~~$160.9 million to PSNH and ~~$48.2 million to WMECO. 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~~$51.0 million to WMECO. Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas are parties to a five-year $1.45 billion revolving credit facility. ~~Effective September 26, 2016, the~~The revolving credit ~~facility’s~~facility's termination date ~~was extended for one additional year to~~is September 4, 2021. The revolving credit facility serves to backstop Eversource ~~parent’s~~parent's $1.45 billion commercial paper program. There were no borrowings outstanding on the revolving credit facility as of ~~September 30, 2016~~March 31, 2017 or December 31, ~~2015.~~2016.

NSTAR Electric has a $450 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. As of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, NSTAR Electric had ~~$36.0~~$174.5 million and ~~$62.5~~$126.5 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving ~~$414.0~~$275.5 million and ~~$387.5~~$323.5 million of available borrowing capacity as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, respectively. The weighted-average interest rate on these borrowings as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015~~2016 was ~~0.42~~0.86 percent and ~~0.40~~0.71 percent, respectively. NSTAR Electric is a party to a five-year $450 million revolving credit facility. ~~Effective September 26, 2016, the~~The revolving credit ~~facility’s~~facility's termination date ~~was extended for one additional year to~~is September 4, 2021. The revolving credit facility serves to backstop NSTAR ~~Electric’s~~Electric's $450 million commercial paper program. There were no borrowings outstanding on the revolving credit facility as of ~~September 30, 2016~~March 31, 2017 or December 31, ~~2015.~~2016.

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 parent to CL&P, PSNH and WMECO are eliminated in consolidation on ~~Eversource’s~~Eversource's balance sheets.

~~Short-Term Borrowing Limits:~~ The amount of short-term borrowings that may be incurred by NSTAR Electric is subject to periodic approval by the FERC. On August 8, 2016, 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, through October 23, 2018.

Long-Term Debt Issuances: In March ~~2016,~~2017, Eversource parent issued ~~$250~~$300 million of ~~2.50~~2.75 percent Series IK Senior Notes due to mature in ~~2021 and $250 million of 3.35 percent Series J Senior Notes due to mature in 2026.~~2022. The proceeds, net of issuance costs, were used to repay short-term borrowings under the Eversource parent commercial paper program.

In ~~May 2016, NSTAR Electric~~March 2017, CL&P issued ~~$250~~$300 million of ~~2.70~~3.20 percent ~~debentures,~~2017 Series A First and Refunding Mortgage Bonds due to mature in ~~2026. The proceeds, net of issuance costs, were used to repay short-term borrowings under the NSTAR Electric commercial paper program and fund capital expenditures and working capital.~~

~~In June 2016, WMECO issued $50 million of 2.75 percent Series H Senior Notes, due to mature in 2026.~~2027. The proceeds, net of issuance costs, were used to repay short-term borrowings.

Long-Term Debt Repayments: In ~~May 2016, NSTAR Electric~~March 2017, CL&P repaid at maturity ~~$200~~the $150 million ~~variable rate debentures,~~5.375 percent 2007 Series A First and Refunding Mortgage Bonds, using ~~short-term~~short term borrowings.

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

7. PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS

Eversource Service sponsors a defined benefit retirement plan ~~(Pension Plan)~~("Pension Plan") that covers eligible ~~employees, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO.~~participants. In addition to the Pension Plan, Eversource maintains non-qualified defined benefit retirement plans sponsored by Eversource Service ~~(SERP Plans)~~("SERP Plans"), which provide benefits in excess of Internal Revenue Code limitations to eligible ~~participants consisting of current and retired employees.~~participants. Eversource Service also sponsors a defined benefit postretirement ~~plans~~plan that ~~provide certain benefits, primarily medical, dental and~~provides life insurance and a health reimbursement arrangement created for the purpose of reimbursing retirees and dependents for health insurance premiums and certain medical expenses, to ~~retired employees~~eligible participants that met certain age and service eligibility requirements ~~including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO (PBOP Plan).~~

~~Effective January 1, 2016, the Company refined its method of estimating the discount rate for the service and interest cost components of Pension and~~ ("PBOP expense from the yield-curve approach to the spot rate methodology, which provides a more precise measurement by matching projected cash flows to the corresponding spot rates on the yield curve. Historically, these components were estimated using the same weighted-average discount rate as for the funded status. The discount rates used to estimate the 2016 service cost were 4.89 percent and 4.09 percent for the Pension and PBOP plans, respectively. The discount rates used to estimate the 2016 interest cost were 3.80 percent and 2.88 percent for the Pension and PBOP plans, respectively. The total pre-tax benefit of this change on Pension and PBOP expense, prior to the capitalized portion and amounts deferred and recovered through rate reconciliation mechanisms, for the three months ended September 30, 2016 was $11.5 million and $2.5 million for the Pension and PBOP plans, respectively, and $35 million and $7.5 million for the nine months ended September 30, 2016, respectively.Plan").

In August 2016, the Company amended its PBOP Plan, which standardized separate benefit structures that existed within the plan and made other benefit changes. The amendment required a remeasurement of the benefit obligation using current assumptions, including updated discount rates and asset values. The discount rate used to remeasure the benefit obligation was 3.62 percent. The remeasurement resulted in a prior service credit of $5.3 million for the three months ended March 31, 2017, which was reflected as a reduction to the benefit liability of approximately $244 million, offset by an increase to the unamortized actuarial losses of approximately $142 million driven primarily by the decrease in the discount rate. Overall, the impact of the remeasurement reduced the PBOP plan’s accumulated projected benefit obligation and regulatory assets by approximately $102 million and $106 million, respectively, and increased accumulated other comprehensive losses by $4.0 million. The remeasurement resulted in a decrease in the net periodic benefit ~~costs~~expense for PBOP benefits, prior to the capitalized portion and amounts deferred and recovered through rate reconciliation mechanisms, of approximately $10 million, which will be recorded in the period August 1, 2016 through December 31, 2016, and mostbenefits. The majority of this amount will be deferred for future refund to customers.

The components of net periodic benefit expense for the Pension, SERP and PBOP Plans are shown below. The net periodic benefit expense and the intercompany allocations, less the capitalized portions of pension, SERP and PBOP amounts, are included in Operations and Maintenance expense on the statements of income. Capitalized ~~pension and PBOP~~ amounts relate to employees working on capital projects and are included in Property, Plant and Equipment, Net on the balance sheets. Pension, SERP and 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.


	Pension and SERP												Pension and SERP
Eversource	For the Three Months Ended						For the Nine Months Ended						For the Three Months Ended
(Millions of Dollars)	September 30, 2016			September 30, 2015 ⁽¹⁾			September 30, 2016			September 30, 2015 ⁽¹⁾			March 31, 2017			March 31, 2016
Service Cost	$	18.6		$	22.7		$	56.6		$	68.7		$	18.7		$	19.4
Interest Cost	46.4			56.9			139.2			170.3			46.3			46.5
Expected Return on Plan Assets	(79.4		)	(83.9		)	(238.5		)	(252.1		)
Expected Return on Pension Plan Assets													(83.5		)	(79.6		)
Actuarial Loss	31.4			36.5			94.2			111.9			33.6			31.5
Prior Service Cost	0.9			0.9			2.6			2.7			1.1			0.9
Total Net Periodic Benefit Expense	$	17.9		$	33.1		$	54.1		$	101.5		$	16.2		$	18.7
Capitalized Pension Expense	$	5.4		$	9.8		$	16.8		$	31.3		$	5.4		$	6.1

	PBOP												PBOP
Eversource	For the Three Months Ended						For the Nine Months Ended						For the Three Months Ended
(Millions of Dollars)	September 30, 2016			September 30, 2015 ⁽¹⁾			September 30, 2016			September 30, 2015 ⁽¹⁾			March 31, 2017			March 31, 2016
Service Cost	$	3.0		$	4.1		$	9.2		$	10.3		$	2.4		$	3.1
Interest Cost	7.5			11.8			26.5			30.4			7.2			9.7
Expected Return on Plan Assets	(15.9		)	(16.9		)	(47.3		)	(43.2		)	(15.9		)	(15.7		)
Actuarial Loss	3.0			1.7			5.0			4.5			2.0			1.1
Prior Service Credit	(3.6		)	(0.1		)	(3.7		)	(0.3		)	(5.3		)	(0.1		)
Total Net Periodic Benefit Expense/(Income)	$	(6.0	)	$	0.6		$	(10.3	)	$	1.7
Capitalized PBOP Expense/(Income)	$	(2.6	)	$	—		$	(4.6	)	$	0.1
Total Net Periodic Benefit Income													$	(9.6	)	$	(1.9	)
Capitalized PBOP Income													$	(4.6	)	$	(0.9	)


	Pension and SERP																								Pension and SERP
	For the Three Months Ended September 30, 2016												For the Three Months Ended September 30, 2015												For the Three Months Ended March 31, 2017												For the Three Months Ended March 31, 2016
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH ⁽¹⁾			WMECO			CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH			WMECO
Service Cost	$	4.6		$	3.3		$	2.5		$	0.8		$	6.2		$	3.7		$	3.1		$	1.0		$	4.8		$	3.3		$	2.5		$	0.8		$	5.0		$	3.4		$	2.5		$	0.9
Interest Cost	10.2			8.5			5.1			2.1			12.9			10.0			6.1			2.6			10.5			8.3			5.2			2.1			10.6			8.3			5.1			2.1
Expected Return on Plan Assets	(18.0		)	(16.9		)	(9.6		)	(4.4		)	(19.8		)	(17.5		)	(10.1		)	(4.7		)
Expected Return on Pension Plan Assets																									(18.0		)	(17.6		)	(9.9		)	(4.4		)	(18.2		)	(16.9		)	(9.7		)	(4.4		)
Actuarial Loss	6.3			8.7			2.5			1.3			8.0			8.7			2.9			1.6			6.9			8.6			2.8			1.5			6.7			8.4			2.5			1.4
Prior Service Cost	0.4			—			0.1			0.1			0.4			—			0.1			0.1			0.4			0.1			0.1			0.1			0.4			—			0.1			0.1
Total Net Periodic Benefit Expense/(Income)	$	3.5		$	3.6		$	0.6		$	(0.1	)	$	7.7		$	4.9		$	2.1		$	0.6
Total Net Periodic Benefit Expense																									$	4.6		$	2.7		$	0.7		$	0.1		$	4.5		$	3.2		$	0.5		$	0.1
Intercompany Allocations	$	3.5		$	2.2		$	1.0		$	0.6		$	5.8		$	3.4		$	1.6		$	1.1		$	2.5		$	1.9		$	0.8		$	0.5		$	3.3		$	2.2		$	1.0		$	0.6
Capitalized Pension Expense	$	2.2		$	2.0		$	0.4		$	0.1		$	4.7		$	2.7		$	0.8		$	0.5		$	2.5		$	1.7		$	0.3		$	0.1		$	2.7		$	1.8		$	0.3		$	0.2

	Pension and SERP
	For the Nine Months Ended September 30, 2016												For the Nine Months Ended September 30, 2015
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH ⁽¹⁾			WMECO
Service Cost	$	14.3		$	9.9		$	7.5		$	2.4		$	18.4		$	11.2		$	9.0		$	3.2
Interest Cost	31.2			25.3			15.4			6.3			38.4			30.2			18.1			7.8
Expected Return on Plan Assets	(54.2		)	(50.7		)	(28.9		)	(13.1		)	(59.1		)	(52.5		)	(30.3		)	(14.2		)
Actuarial Loss	19.2			25.8			7.5			4.1			24.2			27.0			8.8			4.8
Prior Service Cost	1.1			—			0.3			0.2			1.1			0.1			0.4			0.2
Total Net Periodic Benefit Expense/(Income)	$	11.6		$	10.3		$	1.8		$	(0.1	)	$	23.0		$	16.0		$	6.0		$	1.8
Intercompany Allocations	$	10.3		$	6.7		$	3.0		$	1.9		$	18.0		$	10.3		$	5.0		$	3.3
Capitalized Pension Expense	$	7.1		$	5.7		$	1.0		$	0.3		$	14.1		$	8.6		$	2.6		$	1.4


	PBOP
	For the Three Months Ended September 30, 2016												For the Three Months Ended September 30, 2015
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH ⁽¹⁾			WMECO
Service Cost	$	0.6		$	0.6		$	0.4		$	0.1		$	0.5		$	1.3		$	0.3		$	0.1
Interest Cost	1.3			2.5			0.7			0.3			1.8			4.8			1.0			0.3
Expected Return on Plan Assets	(2.5		)	(6.4		)	(1.4		)	(0.6		)	(2.8		)	(6.8		)	(1.5		)	(0.6		)
Actuarial Loss	0.5			1.2			0.2			—			0.2			0.6			0.1			—
Prior Service Cost/(Credit)	0.2			(2.9		)	0.1			—			—			(0.1		)	—			—
Total Net Periodic Benefit Expense/(Income)	$	0.1		$	(5.0	)	$	—		$	(0.2	)	$	(0.3	)	$	(0.2	)	$	(0.1	)	$	(0.2	)
Intercompany Allocations	$	—		$	(0.1	)	$	—		$	—		$	0.4		$	0.2		$	0.1		$	0.1
Capitalized PBOP Expense/(Income)	$	—		$	(2.2	)	$	—		$	(0.1	)	$	(0.1	)	$	—		$	0.1		$	—

	PBOP																								PBOP
	For the Nine Months Ended September 30, 2016												For the Nine Months Ended September 30, 2015												For the Three Months Ended March 31, 2017												For the Three Months Ended March 31, 2016
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH ⁽¹⁾			WMECO			CL&P			NSTAR Electric			PSNH			WMECO			CL&P			NSTAR Electric			PSNH			WMECO
Service Cost	$	1.4		$	2.5		$	0.9		$	0.3		$	1.6		$	4.0		$	1.0		$	0.3		$	0.5		$	0.4		$	0.3		$	0.1		$	0.5		$	0.9		$	0.3		$	0.1
Interest Cost	4.0			10.3			2.2			0.8			5.4			14.2			2.9			1.1			1.4			2.1			0.8			0.3			1.4			4.0			0.8			0.3
Expected Return on Plan Assets	(7.6		)	(19.2		)	(4.2		)	(1.7		)	(8.3		)	(20.5		)	(4.4		)	(1.9		)	(2.4		)	(6.6		)	(1.3		)	(0.5		)	(2.6		)	(6.4		)	(1.4		)	(0.6		)
Actuarial Loss	0.9			1.7			0.5			—			0.5			1.8			0.4			—			0.2			0.9			0.1			—			0.2			0.2			0.1			—
Prior Service Cost/(Credit)	0.2			(2.9		)	0.1			—			—			(0.1		)	—			—			0.3			(4.3		)	0.1			—			—			—			—			—
Total Net Periodic Benefit Income	$	(1.1	)	$	(7.6	)	$	(0.5	)	$	(0.6	)	$	(0.8	)	$	(0.6	)	$	(0.1	)	$	(0.5	)	$	—		$	(7.5	)	$	—		$	(0.1	)	$	(0.5	)	$	(1.3	)	$	(0.2	)	$	(0.2	)
Intercompany Allocations	$	0.3		$	—		$	—		$	—		$	1.4		$	0.7		$	0.3		$	0.3		$	(0.3	)	$	(0.3	)	$	(0.1	)	$	—		$	0.2		$	0.1		$	—		$	—
Capitalized PBOP Expense/(Income)	$	(0.5	)	$	(3.3	)	$	—		$	(0.3	)	$	(0.2	)	$	(0.1	)	$	0.2		$	(0.1	)
Capitalized PBOP Income																									$	(0.1	)	$	(3.8	)	$	—		$	—		$	(0.2	)	$	(0.6	)	$	—		$	(0.1	)


⁽¹⁾	~~Amounts excluded approximately $0.8 million and $2.4 million for the three and nine months ended September 30, 2015, respectively, that represented amounts included in other deferred debits.~~

8. COMMITMENTS AND CONTINGENCIES

A. Environmental Matters

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 each believes it is substantially in compliance with all enacted laws and regulations.

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


	As of September 30, 2016			As of December 31, 2015			As of March 31, 2017			As of December 31, 2016
	Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)
Eversource	63	$	59.7	64	$	51.1	60	$	58.2	61	$	65.8
CL&P	14	4.7		14	4.6		14	5.3		14	4.9
NSTAR Electric	14	2.3		15	2.4		13	1.0		13	3.2
PSNH	12	4.3		12	4.5		11	5.3		11	5.3
WMECO	4	0.7		4	0.6		4	0.7		4	0.6

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 ~~$53.9~~$53.0 million and ~~$45.5~~$59.0 million as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, respectively, and related primarily to the natural gas business segment. The reduction in the reserve balance at the MGP sites was primarily due to a change in cost estimates at one site.

These reserve estimates are subjective in nature as they take into consideration several different remediation options at each specific site. The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of ~~Eversource’s,~~Eversource's, CL~~&P’s,~~&P's, NSTAR ~~Electric’s, PSNH’s,~~Electric's, PSNH's, and ~~WMECO’s~~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.

B. 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 Eversource Gas Transmission LLC, a wholly-owned subsidiary, to guarantee the payment of the ~~subsidiary’s~~subsidiary's capital contributions for its investment in the Access Northeast project. The guaranty will not exceed $206 million and decreases as capital contributions are made. The guaranty will expire upon the earlier of the full performance of the guaranteed obligations or December 31, 2021.

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~~parent's obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations. Eversource parent has also entered into a guaranty on behalf of NPT under which Eversource parent will guarantee ~~NPT’s~~NPT's obligations under ~~its letter of credit~~a facility with a financial institution pursuant to which NPT may request letters of credit in an aggregate amount of up to approximately $14 million.

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

Management does not anticipate a material impact to ~~Net Income~~net income or cash flows as a result of these various guarantees and indemnifications.

The following table summarizes Eversource ~~parent’s~~parent's exposure to guarantees and indemnifications of its subsidiaries to external parties, as of ~~September 30, 2016:~~March 31, 2017:


Company	Description	Maximum Exposure (in millions)		Expiration Dates	Description	Maximum Exposure (in millions)		Expiration Dates
On behalf of subsidiaries:
Eversource Gas Transmission LLC	Access Northeast Project Capital Contributions Guaranty	$	186.5	2021	Access Northeast Project Capital Contributions Guaranty	$	185.1	2021
Various	Surety Bonds⁽¹⁾	$	37.1	2016 - 2018	Surety Bonds⁽¹⁾	38.7		2017 - 2018
Eversource Service and Rocky River Realty Company	Lease Payments for Vehicles and Real Estate	$	9.8	2019 - 2024	Lease Payments for Vehicles and Real Estate	8.8		2019 - 2024


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

C. ~~Spent Nuclear Fuel Litigation - Yankee Companies~~

The Yankee Companies have filed separate complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE’s failure to provide for a permanent facility to store spent nuclear fuel pursuant to the terms of the 1983 spent fuel and high level waste disposal contracts between the Yankee Companies and the DOE. The court had previously awarded the Yankee Companies damages for Phase I and Phase II of litigation resulting from the DOE’s failure to meet its contractual obligations. Phase I covered damages incurred in the years 1998 through 2002 and Phase II covered damages incurred in the years 2001 through 2008 for CYAPC and YAEC and from 2002 through 2008 for MYAPC.

~~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, followed by a post-trial briefing that concluded on October 14, 2015. On March 25, 2016, the court issued its decision and awarded CYAPC, YAEC and MYAPC damages of $32.6 million, $19.6 million and $24.6 million, respectively. In total, the Yankee Companies were awarded $76.8 million of the $77.9 million in damages sought in Phase III. The decision became final on July 18, 2016, and the Yankee Companies received the awards from the DOE on October 14, 2016. The Yankee Companies have filed a request with FERC seeking approval of the proposed distribution of certain amounts of the awarded damages proceeds to member companies, including CL&P, NSTAR Electric, PSNH, and WMECO. Subject to receipt of FERC approval, CYAPC and MYAPC expect to be able to make distributions in December 2016. MYAPC also anticipates refunding approximately $57 million from its spent nuclear fuel trust, a portion of which will be refunded to the Eversource utility subsidiaries. In total, Eversource expects to receive approximately $26 million, of which CL&P expects to receive $13.6 million, NSTAR Electric expects to receive $5 million, PSNH expects to receive $3.9 million, and WMECO expects to receive $3.6 million. These anticipated amounts will be refunded to the customers of the respective Eversource utility subsidiaries.

D. FERC ROE Complaints

Four separate complaints have been filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively the ~~“Complainants”~~"Complainants"). In each of the first three complaints, the Complainants challenged the ~~NETOs’~~NETOs' base ROE of 11.14 percent that had been utilized since ~~2006~~2005 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~~arising from the separate complaints. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE of 10.57 percent and the maximum ROE for transmission incentive ("incentive cap") of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

In response to appeals of the FERC decision in the first complaint filed by the NETOs and the Complainants, the D.C. Circuit Court of Appeals (the "Court") issued a decision on April 14, 2017 vacating and remanding the FERC's decision. The Court found that the FERC ~~ordered a 10.57~~failed to make an explicit finding that the prior 11.14 percent base ROE was unjust and unreasonable, as required under Section 206 of the Federal Power Act, before it could set a new base ROE. The Court also found that the FERC did not provide a rational connection between the record evidence and its decision to select the midpoint of the upper half of the zone of reasonableness for the new base ROE.

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



Complaint	15-Month Time Period of Complaint (Beginning as of Complaint Filing Date)	Original Base ROE Authorized by FERC at Time of Complaint Filing Date ⁽¹⁾	Base ROE Subsequently Authorized by FERC for First Complaint Period and also Effective from October 16, 2014 through April 14, 2017 ⁽¹⁾	Reserve (Pre-Tax and Excluding Interest) as of March 31, 2017 (in millions)		FERC ALJ Recommendation of Base ROE on Second and Third Complaints (Issued March 22, 2016)
First	10/1/2011 - 12/31/2012	11.14%	10.57%	$—	⁽²⁾	N/A
Second	12/27/2012 - 3/26/2014	11.14%	N/A	39.1	⁽³⁾	9.59%
Third	7/31/2014 - 10/30/2015	11.14%	10.57%	—		10.90%
Fourth	4/29/2016 - 7/28/2017	10.57%	10.57%	—		N/A

⁽¹⁾ The total ROE between October 1, 2011 and October 15, 2014 was within a range of 11.14 percent to 13.1 percent. In 2014, as a result of a FERC order, the incentive cap was set at 11.74 percent for the first complaint ~~refund~~ period and ~~prospectively~~also effective from October 16, 2014 and that a utility’s total or maximum ROE for any incentive project shall not exceed the top of the new zone of reasonableness, which was set at 11.74 percent. In late 2014, the NETOs made a compliance filing, andthrough April 14, 2017.

⁽²⁾ CL&P, NSTAR Electric, PSNH and WMECO have refunded all amounts associated with the first complaint ~~period. The NETOs~~period, totaling $38.9 million (pre-tax and ~~Complainants have appealed the decision in the first complaint to the D.C. Circuit Court of Appeals. A court decision is expected in late 2016 or early 2017.~~

~~The Company has recorded reserves across the complaint periods~~excluding interest) at ~~its electric subsidiaries. In the first nine months of 2015, the Company recognized a pre-tax charge to earnings (excluding interest) of $20~~Eversource (including $22.4 million ~~of which $12.5 million was recorded~~ at CL&P, ~~$2.4~~$8.4 million at NSTAR Electric, $1$2.8 million at PSNH, and ~~$4.1~~$5.3 million at ~~WMECO. The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues.~~

~~For the second and third complaints, the state parties, municipal utilities and FERC trial staff each believe that~~WMECO), reflecting both the base ROE ~~should be reduced to an amount lower than 11.14 percent. FERC’s determination to set these cases for hearing was appealed to the D.C. Circuit Court of Appeals,~~ and ~~is being held in abeyance pending a final FERC order. On March 22, 2016,~~incentive cap prescribed by the FERC ~~ALJ issued an initial decision on~~order.

⁽³⁾ The reserve represents the ~~second and third complaints. For~~difference between the ROEs billed during the second complaint period ~~the FERC ALJ recommended a zone of reasonableness of 7.12 percent to 10.42 percent~~ and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve was $21.4 million for CL&P, $8.5 million for NSTAR Electric, $3.1 million for PSNH, and $6.1 million for WMECO as of 9.59 percent. For the third complaint period, the FERC ALJ recommended a zone of reasonableness of 7.04 percent to 12.19 percent and a base ROE of 10.90 percent. The FERC ALJ also affirmed that the maximum ROE for transmission incentive projects should be the top of the zone of reasonableness. The NETOs filed briefs on April 21, 2016, in which the NETOs identified corrections and requested changes that should be made to the FERC ALJ’s recommendations. A final FERC order is expected in late 2016 or earlyMarch 31, 2017.

~~The~~At this time, the Company ~~believes that the~~cannot reasonably estimate a range of ~~potential~~gain or loss for the complaint proceedings. The Court decision did not provide a reasonable basis for a change to the March 31, 2017 reserve balance of $39.1 million (pre-tax and excluding interest) for the second complaint period, (the 15-month period beginning December 27, 2012) is from a base ROE of 10.57 percent to a base ROE of 9.59 percent. As the FERC ALJ initial decision on the third complaint recommended a base ROE of 10.90 percent,and the Company ~~concluded there is currently no range of potential loss~~has not changed its reserves or recognized ROEs for that complaint period (the 15-month period beginning July 31, 2014). Given the differences between the recommended base ROEs in the FERC ALJ’s initial decision on the second and third complaints, as well as other factors, the Company is unable to predict the outcomeany of the final FERC order on these two complaints. The Company does not believe any base ROE outcome within the 10.57 percent to 9.59 percent range is more likely than the base ROEs used to record the current revenues and reserves, and therefore the Company believes that the current reserves for the second complaint ~~period are appropriate at this time.~~periods.

The impact of a 10 basis point change to the existing base ROE of 10.57 percent would affect Eversource’s after-tax earnings by approximately $3 million for each of the 15-month second and third complaint periods. If the Company adjusted its reserves based on the recommendations in the FERC ALJ initial decision (for both the base ROE and maximum ROE for transmission incentive projects) for the second and third complaints, then it would result in an after-tax increase of approximately $34 million and an after-tax decrease of approximately $8 million, respectively, to the existing reserves.

~~For the~~fourth complaint, filed April 29, 2016, certain municipal utilities claimed the current base ROE of 10.57 percent and the incentive cap of 11.74 percent are unjust and unreasonable. The NETOs answered on June 3, 2016 and requested that FERC dismiss the complaint. On September 20, 2016, the FERC issued an order establishing hearing and settlement judge procedures~~and set a 15-month complaint period beginning April 29, 2016.~~ Management cannot at this time predict the ultimate ~~outcome~~effect of ~~this proceeding~~the Court decision on any of the complaint periods or the estimated impacts on the financial position, results of operations or cash flows of Eversource, CL&P, NSTAR Electric, PSNH and WMECO. ~~A FERC ALJ initial decision could be received in 2017.~~

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

D. Eversource and NSTAR Electric Boston Harbor Civil Action

On July 15, 2016, the United States Army Corps of Engineers filed a civil action in the United States District Court for the District of Massachusetts under provisions of the Rivers and Harbors Act of 1899 and the Clean Water Act against NSTAR Electric, Harbor Electric Energy Company, a wholly-owned subsidiary of NSTAR Electric ~~(“HEEC”~~("HEEC"), and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the ~~“Defendants”~~"Defendants"). The action alleges that the Defendants failed to comply with certain permitting requirements relating to the placement of the HEEC-owned electric distribution cable beneath Boston Harbor. The action seeks an order to force HEEC to comply with cable depth requirements in the U.S. Army Corps of ~~Engineers’~~Engineers' permit or alternatively to remove the electric distribution cable and cease unauthorized work in U.S. waterways. The action also seeks civil penalties and other costs. Management believes there are valid defenses to the claims and ~~intends to defend~~is defending NSTAR Electric and HEEC vigorously. Concurrently, NSTAR Electric and HEEC are seeking to work collaboratively with all parties for a mutually beneficial resolution. At this time, management is unable to predict the outcome of this action or the impact on ~~Eversource’s~~Eversource's and NSTAR ~~Electric’s~~Electric's financial position, results of operations, or cash flows.

9. PSNH GENERATION ASSET SALE

On June 10, 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement (the ~~Agreement)~~"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. Under the terms of the Agreement, PSNH agreed to divest its generation assets, subject to NHPUC approval. The Agreement provided for a resolution of issues pertaining to ~~PSNH’s~~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 agreed to forego recovery of $25 million of the 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 the first nine months of 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.~~

On July 1, 2016, the NHPUC approved the Agreement in an order that, among other things, instructs PSNH to begin the process ~~to divest~~of divesting its generation assets. The NHPUC selected an auction adviser to assist with the divestiture, and athe final plan and auction process ~~will be determined~~were approved by the NHPUC in November 2016. An intervening appeal alleging that the ~~fourth quarter of 2016. Upon completion of~~auction process and schedule were unreasonable was rejected by the New Hampshire Supreme Court in February 2017. In late March 2017, the formal divestiture process ~~all remaining stranded costs will be recovered via bonds that will be secured by a non-bypassable charge or through recoveries in rates billed~~began. We continue to ~~PSNH’s customers.~~

~~If the NHPUC approves the sale of the assets, the Company expects~~believe the assets will be sold ~~prior to~~by the end of 2017.

The sales price of the ~~generating~~generation assets could be less than the carrying value, but the Company believes that full recovery of ~~PSNH’s~~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 via bonds that will be secured by a non-bypassable charge or through recoveries in future ~~rates.~~rates billed to PSNH's customers.

As of ~~September 30, 2016, PSNH’s~~March 31, 2017, PSNH's generation assets were as follows:


(Millions of Dollars)
Gross Plant	$	1,191.0		$	1,192.6
Accumulated Depreciation	(552.1		)	(564.1		)
Net Plant	638.9			628.5
Fuel, Materials, Supplies and Allowances	161.9
Fuel				98.3
Materials and Supplies				48.5
Emission Allowances				19.7
Total Generation Assets				$	795.0

As of March 31, 2017, current and long-term liabilities associated with PSNH's generation assets included Accounts Payable of $30.1 million, Other Current Liabilities of $21.7 million, AROs of $20.3 million, and Accrued Pension, SERP and PBOP of $23.7 million.

10. 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~~&P's and NSTAR ~~Electric’s~~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:


	As of September 30, 2016				As of December 31, 2015				As of March 31, 2017				As of December 31, 2016
Eversource (Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	166.6	$	155.6	$	157.9	$	155.6	$	156.6	$	155.6	$	158.3
Long-Term Debt	9,609.0		10,454.8		9,034.5		9,425.9		10,041.8		10,428.0		9,603.2		9,980.5


	CL&P				NSTAR Electric				PSNH				WMECO				CL&P				NSTAR Electric				PSNH				WMECO
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
As of September 30, 2016:
As of March 31, 2017:
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	122.2	$	43.0	$	44.4	$	—	$	—	$	—	$	—	$	116.2	$	113.5	$	43.0	$	43.1	$	—	$	—	$	—	$	—
Long-Term Debt	2,765.4		3,216.8		2,078.0		2,338.8		1,071.8		1,142.9		566.7		616.9		2,913.2		3,179.5		2,078.5		2,202.9		1,072.3		1,115.2		566.4		596.8

As of December 31, 2015:
As of December 31, 2016:
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	114.9	$	43.0	$	43.0	$	—	$	—	$	—	$	—	$	116.2	$	114.7	$	43.0	$	43.6	$	—	$	—	$	—	$	—
Long-Term Debt	2,763.7		3,031.6		2,029.8		2,182.4		1,071.0		1,121.2		517.3		551.8		2,766.0		3,049.6		2,078.1		2,201.6		1,072.0		1,109.7		566.5		589.0

Derivative Instruments and Marketable Securities: Derivative instruments and investments in marketable securities are carried at fair value. For further information, see Note 4, ~~“Derivative~~"Derivative Instruments,”" and Note 5, ~~“Marketable~~"Marketable Securities,”" to the financial statements.

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

11. ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

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


																														For the Three Months Ended March 31, 2017														For the Three Months Ended March 31, 2016
	For the Nine Months Ended September 30, 2016														For the Nine Months Ended September 30, 2015															Qualified			Unrealized											Qualified				Unrealized
	Qualified Cash Flow Hedging Instruments			Unrealized Gains/(Losses) on Marketable Securities			Defined Benefit Plans				Total				Qualified Cash Flow Hedging Instruments				Unrealized Gains/(Losses) on Marketable Securities				Defined Benefit Plans				Total			Cash Flow			Gains											Cash Flow				Gains/(Losses)
Eversource (Millions of Dollars)	Qualified Cash Flow Hedging Instruments									Hedging					Qualified Cash Flow Hedging Instruments			on Marketable					Defined Benefit Plans			Defined								Hedging			on Marketable				Defined
Eversource (Millions of Dollars)																														Instruments			Securities			Benefit Plans				Total				Instruments				Securities				Benefit Plans				Total
Eversource (Millions of Dollars)	$	(10.3	)	Unrealized Gains/(Losses) on Marketable Securities		$	Defined Benefit Plans		(1.9	)	Total			$	(54.6	)		$	Unrealized Gains/(Losses) on Marketable Securities		(66.8	)		$	(12.4	)	Total			$	0.7		$	(62.3	)	$	(74.0	)	$	(8.2	)		$	0.4			$	(57.5	)		$	(65.3	)		$	(10.3	)		$	(1.9	)	$	(54.6	)	$	(66.8	)

OCI Before Reclassifications	—			2.3			(5.3		)		(3.0		)		—				(3.9		)		(0.4		)		(4.3		)	—			1.7			—				1.7				—				0.2				—				0.2
Amounts Reclassified from AOCI	1.6			—			2.6				4.2				1.5				—				3.3				4.8
Amounts Reclassified from AOCL																														0.5			—			1.0				1.5				0.5				—				0.9				1.4
Net OCI	1.6			2.3			(2.7		)		1.2				1.5				(3.9		)		2.9				0.5			0.5			1.7			1.0				3.2				0.5				0.2				0.9				1.6
Balance as of End of Period	$	(8.7	)	$	0.4		$	(57.3	)		$	(65.6	)		$	(10.9	)		$	(3.2	)		$	(59.4	)		$	(73.5	)	$	(7.7	)	$	2.1		$	(56.5	)		$	(62.1	)		$	(9.8	)		$	(1.7	)		$	(53.7	)		$	(65.2	)

~~Eversource’s~~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~~AOCL 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~~AOCL into Interest Expense over the remaining life of the associated long-term debt. Such interest rate swaps are not material to their respective financial statements.

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses and prior service costs that arose during the year and were recognized in ~~AOCI. For further information see Note 7, “Pension Benefits and Postretirement Benefits Other Than Pensions.”~~AOCL. The unamortized actuarial gains and losses and prior service costs on the defined benefit plans are amortized from ~~AOCI~~AOCL into Operations and Maintenance expense over the average future employee service period, and are reflected in amounts reclassified from ~~AOCI.~~ AOCL. For further information, see Note 7, "Pension Benefits and Postretirement Benefits Other Than Pensions."

12. COMMON SHARES

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


	Shares					Shares
			Authorized as of September 30, 2016 and	Issued as of				Authorized as of March 31, 2017 and	Issued as of
	Par Value		December 31, 2015	September 30, 2016	December 31, 2015	Par Value		December 31, 2016	March 31, 2017	December 31, 2016
Eversource	$	5	380,000,000	333,878,402	333,862,615	$	5	380,000,000	333,878,402	333,878,402
CL&P	$	10	24,500,000	6,035,205	6,035,205	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	100	100	$	1	100,000,000	100	100
PSNH	$	1	100,000,000	301	301	$	1	100,000,000	301	301
WMECO	$	25	1,072,471	434,653	434,653	$	25	1,072,471	434,653	434,653

As of both ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, there were ~~16,671,366~~16,992,594 Eversource common shares held as treasury shares. As of ~~September 30, 2016~~both March 31, 2017 and December 31, ~~2015,~~2016, Eversource common shares outstanding were ~~317,207,036 and 317,191,249, respectively.~~ 316,885,808.

13. COMMON ~~SHAREHOLDERS’~~SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for each of the three months ended ~~September 30, 2016~~March 31, 2017 and ~~2015, and $5.6 million for the nine months ended September 30, 2016 and 2015.~~2016. 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 ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015.~~2016. On the Eversource balance sheets, Common ~~Shareholders’~~Shareholders' Equity was fully attributable to the parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.

14. EARNINGS PER SHARE

Basic EPS is computed based upon the weighted average number of common shares outstanding during each period. Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards as if they were converted into common shares. The dilutive effect of unvested RSU and performance share awards and unexercised stock options is calculated using the treasury stock method. RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. For the three ~~and nine~~ months ended ~~September 30,~~March 31, 2017 and 2016, ~~and 2015,~~ there were no antidilutive share awards excluded from the ~~computation.~~computation of diluted EPS.

The following table sets forth the components of basic and diluted EPS:


Eversource (Millions of Dollars, except share information)	For the Three Months Ended				For the Nine Months Ended				For the Three Months Ended
Eversource (Millions of Dollars, except share information)	September 30, 2016		September 30, 2015		September 30, 2016		September 30, 2015		March 31, 2017		March 31, 2016
Net Income Attributable to Common Shareholders	$	265.3	$	235.9	$	713.1	$	696.7	$	259.5	$	244.2

Weighted Average Common Shares Outstanding:
Basic	317,787,836		317,452,212		317,696,823		317,296,107		317,463,151		317,517,141
Dilutive Effect	789,243		953,057		814,786		1,099,935		661,385		963,909
Diluted	318,577,079		318,405,269		318,511,609		318,396,042		318,124,536		318,481,050
Basic EPS	$	0.83	$	0.74	$	2.24	$	2.20
Diluted EPS	$	0.83	$	0.74	$	2.24	$	2.19
Basic and Diluted EPS									$	0.82	$	0.77

15. SEGMENT INFORMATION

Presentation: Eversource is organized ~~into~~among the Electric Distribution, Electric Transmission and Natural Gas Distribution reportable segments and Other based on a combination of factors, including the characteristics of each ~~segments’~~segments' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates. These reportable segments represent substantially all of ~~Eversource’s~~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~~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)4) the results of other unregulated subsidiaries, which are not part of its core business. In addition, Other in the tables below includes Eversource parent's equity ownership interests in certain natural gas pipeline projects owned by Enbridge, Inc., the Bay State Wind project, an energy investment fund, and two companies that transmit hydroelectricity imported from the Hydro-Quebec system in Canada. In the ordinary course of business, Yankee Gas and NSTAR Gas purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline projects described above. These affiliate transaction costs total approximately $62.5 million annually and are classified as Purchased Power, Fuel and Transmission on the Eversource statements of income.

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~~Eversource's reportable segments are determined based upon the level at which ~~Eversource’s~~Eversource's chief operating decision maker assesses performance and makes decisions about the allocation of company resources. Each of ~~Eversource’s~~Eversource's subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, has one reportable segment. ~~Eversource’s~~Eversource's operating segments and reporting units are consistent with its reportable business segments.

~~Eversource’s~~Eversource's segment information is as follows:


	For the Three Months Ended September 30, 2016
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Other			Eliminations			Total
Operating Revenues	$	1,623.4		$	99.2		$	306.8		$	211.5		$	(201.2	)	$	2,039.7
Depreciation and Amortization	(154.8		)	(15.2		)	(47.1		)	(8.6		)	0.5			(225.2		)
Other Operating Expenses	(1,146.8		)	(87.8		)	(90.2		)	(179.3		)	199.5			(1,304.6		)
Operating Income/(Loss)	321.8			(3.8		)	169.5			23.6			(1.2		)	509.9
Interest Expense	(49.0		)	(10.2		)	(26.9		)	(15.1		)	1.3			(99.9		)
Other Income, Net	5.3			0.6			6.3			256.9			(255.5		)	13.6
Net Income Attributable to Common Shareholders	$	170.1		$	(7.0	)	$	88.4		$	268.5		$	(254.7	)	$	265.3

	For the Nine Months Ended September 30, 2016																		For the Three Months Ended March 31, 2017
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Other			Eliminations			Total			Electric Distribution			Natural Gas Distribution			Electric Transmission			Other			Eliminations			Total
Operating Revenues	$	4,362.6		$	622.3		$	892.5		$	636.8		$	(651.7	)	$	5,862.5		$	1,401.1		$	403.6		$	316.9		$	236.3		$	(252.8	)	$	2,105.1
Depreciation and Amortization	(380.9		)	(47.9		)	(137.7		)	(23.1		)	1.6			(588.0		)	(129.8		)	(21.7		)	(50.6		)	(9.2		)	0.5			(210.8		)
Other Operating Expenses	(3,230.1		)	(462.4		)	(245.7		)	(564.7		)	650.2			(3,852.7		)	(1,041.9		)	(289.6		)	(90.0		)	(216.6		)	252.8			(1,385.3		)
Operating Income	751.6			112.0			509.1			49.0			0.1			1,421.8			$	229.4		$	92.3		$	176.3		$	10.5		$	0.5		$	509.0
Interest Expense	(144.6		)	(30.8		)	(82.2		)	(45.8		)	4.8			(298.6		)	$	(48.2	)	$	(10.6	)	$	(28.1	)	$	(19.7	)	$	3.2		$	(103.4	)
Other Income, Net	11.6			0.5			14.2			781.4			(784.0		)	23.7			5.0			0.3			4.9			328.9			(325.5		)	13.6
Net Income Attributable to Common Shareholders	$	381.3		$	51.9		$	266.6		$	791.7		$	(778.4	)	$	713.1		114.1			50.8			94.2			322.2			(321.8		)	259.5
Cash Flows Used for Investments in Plant	$	570.9		$	170.3		$	536.2		$	81.8		$	—		$	1,359.2		236.2			64.5			192.6			30.3			—			523.6


	For the Three Months Ended September 30, 2015
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Other			Eliminations			Total
Operating Revenues	$	1,543.7		$	106.2		$	270.4		$	211.6		$	(198.8	)	$	1,933.1
Depreciation and Amortization	(84.5		)	(17.5		)	(42.4		)	(7.1		)	0.5			(151.0		)
Other Operating Expenses	(1,140.8		)	(92.7		)	(78.3		)	(199.6		)	198.5			(1,312.9		)
Operating Income/(Loss)	318.4			(4.0		)	149.7			4.9			0.2			469.2
Interest Expense	(47.4		)	(9.2		)	(25.9		)	(11.2		)	1.2			(92.5		)
Other Income/(Loss), Net	1.9			(0.2		)	3.8			241.9			(242.2		)	5.2
Net Income Attributable to Common Shareholders	$	167.5		$	(3.7	)	$	78.0		$	234.9		$	(240.8	)	$	235.9

	For the Nine Months Ended September 30, 2015																		For the Three Months Ended March 31, 2016
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Other			Eliminations			Total			Electric Distribution			Natural Gas Distribution			Electric Transmission			Other			Eliminations			Total
Operating Revenues	$	4,686.5		$	799.6		$	787.2		$	655.2		$	(664.9	)	$	6,263.6		$	1,436.1		$	342.6		$	283.3		$	214.2		$	(220.6	)	$	2,055.6
Depreciation and Amortization	(342.1		)	(53.4		)	(122.6		)	(21.5		)	1.6			(538.0		)	(127.7		)	(15.8		)	(45.1		)	(6.9		)	0.5			(195.0		)
Other Operating Expenses	(3,535.7		)	(631.5		)	(225.5		)	(619.4		)	665.2			(4,346.9		)	(1,088.9		)	(233.5		)	(73.0		)	(197.3		)	220.6			(1,372.1		)
Operating Income	808.7			114.7			439.1			14.3			1.9			1,378.7			$	219.5		$	93.3		$	165.2		$	10.0		$	0.5		$	488.5
Interest Expense	(140.6		)	(27.2		)	(79.8		)	(35.4		)	3.4			(279.6		)	$	(48.0	)	$	(10.1	)	$	(28.0	)	$	(14.1	)	$	2.0		$	(98.2	)
Other Income/(Loss), Net	9.6			(0.1		)	11.9			777.0			(774.5		)	23.9			—			(0.3		)	2.6			305.5			(305.8		)	2.0
Net Income Attributable to Common Shareholders	$	418.9		$	57.3		$	225.0		$	764.7		$	(769.2	)	$	696.7		108.4			50.9			85.7			302.5			(303.3		)	244.2
Cash Flows Used for Investments in Plant	$	506.5		$	120.0		$	493.9		$	56.9		$	—		$	1,177.3		184.2			52.1			172.4			22.8			—			431.5

The following table summarizes ~~Eversource’s~~Eversource's segmented total assets:

Eversource
(Millions of Dollars)
Electric
Distribution

Natural Gas
Distribution
Electric
Transmission Other Eliminations Total
As of September 30, 2016 $ 18,140.0
$ 3,149.9
$ 8,454.4
$ 13,624.8
$ (12,286.8 ) $ 31,082.3
As of December 31, 2015 17,981.3
3,104.5
8,019.3
13,256.7
(11,781.5 ) 30,580.3



Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Other		Eliminations			Total
As of March 31, 2017	$	18,343.3	$	3,332.7	$	9,015.6	$	14,590.4	$	(12,926.8	)	$	32,355.2
As of December 31, 2016	18,367.5		3,303.8		8,751.5		14,493.1		(12,862.7		)	32,053.2

EVERSOURCE ENERGY AND SUBSIDIARIES

~~Management’s~~Management's Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis should be read in conjunction with our unaudited condensed consolidated financial statements and related combined notes included in this combined Quarterly Report on Form 10-Q, ~~the combined quarterly reports on Form 10-Q for the quarters ended March 31, 2016 and June 30, 2016,~~ as well as the Eversource ~~2015~~2016 Form 10-K. References in this combined Quarterly Report on Form 10-Q to ~~“Eversource,”~~"Eversource," the ~~“Company,” “we,” “us,”~~"Company," "we," "us," and ~~“our”~~"our" refer to Eversource Energy and its consolidated subsidiaries. All ~~per share~~per-share amounts are reported on a diluted basis. The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P and WMECO are herein collectively referred to as the ~~“financial~~"financial statements.”"

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

The only common equity securities that are publicly traded are common shares of Eversource. The earnings and EPS of each business discussed below do not represent a direct legal interest in the assets and liabilities of such business but rather represent a direct interest in our assets and liabilities as a whole. EPS by business is a financial measure not recognized under GAAP calculated by dividing the Net Income Attributable to Common Shareholders of each business by the weighted average diluted Eversource common shares outstanding for the period. ~~The tabular presentations below also include~~We use this non-GAAP financial ~~measures referencing our third quarter and first nine months of 2016 and 2015 earnings and EPS excluding certain integration costs. We use these non-GAAP financial measures~~measure to evaluate and to provide details of earnings results by business and to more fully compare and explain our third quarter and first nine months of 2015 results without including the impact of these items. Due to the nature and significance of these items on Net Income Attributable to Common Shareholders, webusiness. 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~~This non-GAAP financial ~~measures~~measure 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 this ~~Management’s Discussion and Analysis of Financial Condition and Results of Operations, herein.~~

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”~~"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,”~~"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 and contain uncertainties that may materially affect our actual results, ~~and~~many of which are beyond our control. You should not place undue reliance on the forward-looking statements, as each speaks only as of the date on which such statement is made, and, except as required by federal securities laws, we undertake no obligation to update any forward-looking statement or statements to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time and it is not possible for us to predict all of such factors, nor can we assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements. For more information, see Item 1A, Risk Factors, included in this combined Quarterly Report on Form 10-Q and in ~~Eversource’s 2015~~Eversource's 2016 combined Annual Report on Form 10-K. This combined Quarterly Report on Form 10-Q and ~~Eversource’s 2015~~Eversource's 2016 combined Annual Report on Form 10-K also describe material contingencies and critical accounting policies in the accompanying ~~Management’s~~Management's Discussion and Analysis of Financial Condition and Results of Operations and Combined Notes to Financial Statements. We encourage you to review these items.

Financial Condition and Business Analysis

Executive Summary

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

Results:

We earned ~~$265.3~~$259.5 million, or ~~$0.83 per share, in the third quarter of 2016, and $713.1 million, or $2.24~~$0.82 per share, in the first ~~nine months~~quarter of ~~2016,~~2017, compared with ~~$235.9~~$244.2 million, or ~~$0.74 per share, in the third quarter of 2015, and $696.7 million, or $2.19~~$0.77 per share, in the first ~~nine months~~quarter of ~~2015.~~2016.

Our electric distribution segment, which includes generation, earned ~~$170.1~~$114.1 million, or ~~$0.53 per share, in the third quarter of 2016, and $381.3 million, or $1.20~~$0.36 per share, in the first ~~nine months~~quarter of ~~2016,~~2017, compared with ~~earnings of $167.3~~$108.4 million, or ~~$0.53 per share, in the third quarter of 2015, and $418.7 million, or $1.32~~$0.34 per share, in the first ~~nine months~~quarter of ~~2015.~~

2016. Our electric transmission segment earned ~~$88.4~~$94.2 million, or ~~$0.28 per share, in the third quarter of 2016, and $266.6 million, or $0.84~~$0.30 per share, in the first ~~nine months~~quarter of ~~2016,~~2017, compared with ~~$78.0~~$85.7 million, or ~~$0.24 per share, in the third quarter of 2015, and $225.0 million, or $0.70~~$0.27 per share, in the first ~~nine months~~quarter of ~~2015.~~

2016. Our natural gas distribution segment ~~had a net loss of $7.0 million, or $0.02 per share, in the third quarter of 2016, and earnings of $51.9~~earned $50.8 million, or $0.16 per share, in the first ~~nine months~~quarter of ~~2016,~~2017, compared with $50.9 million, or $0.16 per share, in the first quarter of 2016.

Eversource parent and other companies earned $0.4 million in the first quarter of 2017, compared with a net loss of ~~$3.5 million, or $0.01 per share, in the third quarter of 2015, and earnings of $57.5 million, or $0.18 per share, in the first nine months of 2015.~~

~~Eversource parent and other companies earned $13.8 million in the third quarter of 2016 and $13.3~~$0.8 million in the first ~~nine months of 2016, compared with a net loss of $5.9 million in the third~~ quarter of ~~2015 and $4.5 million in the first nine months of 2015.~~

2016.

Liquidity:

Cash flows provided by operating activities totaled ~~$1.65 billion~~$436.5 million in the first ~~nine months~~quarter of ~~2016,~~2017, compared with ~~$1.35 billion~~$500.0 million in the first ~~nine months~~quarter of ~~2015.~~2016. Investments in property, plant and equipment totaled ~~$1.36 billion~~$523.6 million in the first ~~nine months~~quarter of ~~2016,~~2017, compared with ~~$1.18 billion~~$431.5 million in the first ~~nine months~~quarter of ~~2015.~~2016. Cash and cash equivalents totaled ~~$40.1~~$45.8 million as of ~~September 30, 2016,~~March 31, 2017, compared with ~~$23.9~~$30.3 million as of December 31, ~~2015.~~2016.

In March 2017, Eversource parent issued $300 million of 2.75 percent Series K Senior Notes, due to mature in 2022. The proceeds, net of issuance costs, were used to repay short-term borrowings under the Eversource parent commercial paper program. In March 2017, CL&P issued $300 million of 3.20 percent 2017 Series A First and Refunding Mortgage Bonds due to mature in 2027. The proceeds, net of issuance costs, were used to repay short-term borrowings. Also in March 2017, CL&P repaid at maturity $150 million of 5.375 percent 2007 Series A First and Refunding Mortgage Bonds, using short-term borrowings.

On ~~September 7, 2016,~~May 3, 2017, our Board of Trustees approved a common share dividend payment of ~~$0.445~~$0.475 per share, ~~which was paid~~payable on ~~September~~June 30, ~~2016~~2017 to shareholders of record as of ~~September 19, 2016.~~May 31, 2017.

Strategic, Legislative, Regulatory, Policy and Other Items:

~~In late 2015~~On April 14, 2017, pursuant to appeals the NETOs and ~~early 2016, NSTAR Electric, WMECO~~Complainants filed on the first FERC ROE complaint decision, the D.C. Circuit Court of Appeals issued a decision vacating and ~~a subsidiary of National Grid filed~~remanding the FERC's decision. The Court remanded the case to the FERC for further proceedings consistent with the ~~Massachusetts DPU seeking approval of contracts with Access Northeast for natural gas pipeline capacity and storage. The DPU had determined~~Court's decision.

On March 31, 2017, pursuant to legislation that became law in ~~2015 that it had authority to approve such contracts if they were found to be in the public interest. On August 17,~~ 2016, the Massachusetts ~~Supreme Judicial Court vacated~~EDCs, including NSTAR Electric and WMECO, and the DPU’s 2015 order, holding that the state’s electric utility restructuring statutes precluded the DPU from approving contracts by EDCs for natural gas capacity. In early 2016, PSNH filed with the NHPUC seeking approval of its contract with Access Northeast for natural gas pipeline capacity and storage. On October 6, 2016, contrary to a 2015 recommendation from its staff, the NHPUC ruled that it did not have authority to approve such contracts under the state’s electric utility restructuring statutes. On October 25, 2016, the Connecticut DEEPDOER issued a ~~notice~~joint RFP for 9.45 terawatt hours of ~~cancellation, without prejudice,~~clean energy per year, such as hydropower, land-based wind or solar. The RFP seeks proposals for long-term contracts of its natural gas capacity review process. We are currently reviewing options surrounding Access Northeast and, depending on the outcome of the potential options selected, the timing, configuration and cost of Access Northeast could change.

~~On October 14, 2016, in an important foundational order for NPT, the NHPUC granted NPT public utility status, conditioned on project approval.~~

On October 24, 2016, Eversource was notified that neither the NPT project nor the Clean Energy Connect project were selected in the three-state Clean Energy RFP bidding process. The Company is currently placing efforts on the next round of contracting opportunities, specifically in Massachusetts, where new legislation requires15 to 20 years to provide electric distribution companies ~~to jointly solicit RFPs and enter~~with clean energy generation. Northern Pass will be bid into ~~long-term contracts for large-scale hydro projects.~~

the RFP.

Overview

Consolidated: Below is a summary of our earnings by business, which also reconciles the non-GAAP financial measure of EPS by business to the most directly comparable GAAP measure of diluted EPS, for the ~~third~~first quarter of 2017 and first nine months of 2016 and 2015. Also included in the summary for the third quarter and first nine months of 2015 is a reconciliation of the non-GAAP financial measure of consolidated non-GAAP earnings to the most directly comparable GAAP measure of consolidated Net Income Attributable to Common Shareholders.2016.


	For the Three Months Ended September 30,										For the Nine Months Ended September 30,										For the Three Months Ended March 31,
	2016				2015						2016				2015						2017				2016
(Millions of Dollars, Except Per Share Amounts)	Amount		Per Share		Amount			Per Share			Amount		Per Share		Amount			Per Share
(Millions of Dollars, Except Per-Share Amounts)																					Amount		Per Share		Amount			Per Share
Net Income Attributable to Common Shareholders (GAAP)	$	265.3	$	0.83	$	235.9		$	0.74		$	713.1	$	2.24	$	696.7		$	2.19		$	259.5	$	0.82	$	244.2		$	0.77
Regulated Companies	$	251.5	$	0.79	$	242.2		$	0.76		$	699.8	$	2.20	$	702.3		$	2.20		$	259.1	$	0.82	$	245.0		$	0.77
Eversource Parent and Other Companies	13.8		0.04		(4.6		)	(0.01		)	13.3		0.04		2.2			0.01			0.4		—		(0.8		)	—
Non-GAAP Earnings	N/A		N/A		237.6			0.75			N/A		N/A		704.5			2.21
Integration Costs (after-tax) ⁽¹⁾	N/A		N/A		(1.7		)	(0.01		)	N/A		N/A		(7.8		)	(0.02		)
Net Income Attributable to Common Shareholders (GAAP)	$	265.3	$	0.83	$	235.9		$	0.74		$	713.1	$	2.24	$	696.7		$	2.19		$	259.5	$	0.82	$	244.2		$	0.77


⁽¹⁾	~~The~~ ~~2015~~ ~~integration costs were 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 for the ~~third~~first quarter of 2017 and ~~first nine months of~~ 2016 ~~and 2015~~ is as follows:


	For the Three Months Ended September 30,												For the Nine Months Ended September 30,									For the Three Months Ended March 31,
	2016						2015						2016				2015					2017				2016
(Millions of Dollars, Except Per Share Amounts)	Amount			Per Share			Amount			Per Share			Amount		Per Share		Amount			Per Share
(Millions of Dollars, Except Per-Share Amounts)																						Amount		Per Share		Amount		Per Share
Electric Distribution	$	170.1		$	0.53		$	167.7		$	0.53		$	381.3	$	1.20	$	419.8		$	1.32	$	114.1	$	0.36	$	108.4	$	0.34
Electric Transmission	88.4			0.28			78.0			0.24			266.6		0.84		225.0			0.70		94.2		0.30		85.7		0.27
Natural Gas Distribution	(7.0		)	(0.02		)	(3.5		)	(0.01		)	51.9		0.16		57.5			0.18		50.8		0.16		50.9		0.16
Non-GAAP Earnings	N/A			N/A			242.2			0.76			N/A		N/A		702.3			2.20
Integration Costs (after-tax)	N/A			N/A			(0.4		)	—			N/A		N/A		(1.1		)	—
Net Income - Regulated Companies	$	251.5		$	0.79		$	241.8		$	0.76		$	699.8	$	2.20	$	701.2		$	2.20	$	259.1	$	0.82	$	245.0	$	0.77

Our electric distribution segment earnings increased $2.8 million in the third quarter of 2016, as compared to the third quarter of 2015, due primarily to increased CL&P distribution revenues primarily as a result of higher rate base, and higher generation earnings. These favorable earnings impacts were partially offset by higher depreciation expense and higher property tax and other tax expense.

~~Our electric distribution segment earnings decreased $37.4~~$5.7 million in the first ~~nine months~~quarter of ~~2016,~~2017, as compared to the first ~~nine months~~quarter of ~~2015,~~2016, due primarily to the absence in 2016 of the resolution of NSTAR Electric’s basic service bad debt adder mechanism recorded in the first quarter of 2015 ($14.5 million), the absence in 2016 of the favorable impact associated with thehigher lost base revenues at NSTAR Electric and ~~NSTAR Gas Comprehensive Settlement Agreement recorded in the first quarter of 2015 ($13 million),~~ lower non-decoupled retail electric sales volumes due primarily to increased customer energy conservation efforts and warmer than normal weather in the first quarter of 2016, as compared to the much colder than normal temperatures in the first quarter of 2015, higher depreciation expense, and higher property ~~tax~~ and other tax ~~expense. These unfavorable earnings impacts were~~expense, partially offset by ~~increased CL&P distribution revenues~~lower generation earnings, higher operations and maintenance expense driven primarily ~~as a result of~~by higher ~~rate base and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision,~~storm restoration costs, and higher ~~generation earnings.~~depreciation expense.

Our electric transmission segment earnings increased ~~$10.4~~$8.5 million in the ~~third~~first quarter of ~~2016,~~2017, as compared to the ~~third~~first quarter of ~~2015,~~2016, due primarily to a higher transmission rate base as a result of ~~increased investments~~our continued investment in our transmission infrastructure.

Our electric transmission segment earnings increased $41.6 million in the first nine months of 2016, as compared to the first nine months of 2015, due primarily to a higher transmission rate base as a result of increased investments in our transmission infrastructure and the absence in 2016 of reserve charges of $12.4 million recorded in the first quarter of 2015 associated with the FERC ROE complaint proceedings.

Our natural gas distribution segment earnings decreased ~~$3.5~~$0.1 million in the third quarter of 2016, as compared to the third quarter of 2015, due primarily to a higher effective tax rate in 2016, partially offset by the higher return earned on the NSTAR Gas System Enhancement Program (GSEP) capital tracker mechanism effective in 2016.

~~Our natural gas distribution segment earnings decreased $5.6 million~~ in the first ~~nine months~~quarter of ~~2016,~~2017, as compared to the first ~~nine months~~quarter of ~~2015,~~2016, due primarily to ~~lower non-decoupled~~higher operations and maintenance expense and depreciation expense, partially offset by higher firm natural gas sales volumes driven by ~~the warmer than normal~~colder weather in Connecticut in the first quarter of ~~2016,~~2017, as compared to the ~~much colder than normal temperatures in the~~ first quarter of ~~2015, higher property tax expense~~2016, and higher interest expense. Partially offsetting these unfavorable earnings impacts were lower operations and maintenance expense, the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016, and the higher return earned on the NSTAR Gas GSEP capital tracker mechanism effectiverevenues due to growth in ~~2016.~~new customer base.

Eversource Parent and Other Companies: Eversource parent and other companies had earnings of ~~$13.8 million and $13.3~~$0.4 million in the ~~third~~first quarter ~~and first nine months~~ of ~~2016, respectively,~~2017, compared with a net loss of ~~$5.9 million and $4.5~~$0.8 million in the ~~third~~first quarter ~~and first nine months~~ of ~~2015, respectively.~~2016. The earnings increase ~~in the third quarter and first nine months of 2016~~ was due primarily to higher investment earnings from Eversource parent's equity method investments and a lower effective tax rate, ~~the absence in 2016 of integration costs, and the absence in 2016 of a bad debt reserve recorded in the third quarter of 2015 at Eversource’s unregulated business,~~ partially offset by higher interest expense.

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”~~("Traditional" in the table below). For CL&P and WMECO, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission approved distribution revenue decoupling mechanisms ~~(“Decoupled”~~("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 of $1.059 billion and $132.4 million, respectively. 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.

Fluctuations in natural gas sales volumes in Massachusetts do not impact earnings due to the DPU-approved natural gas distribution revenue decoupling mechanism approved in the last rate case decision ~~(“Decoupled”~~("Decoupled" in the table below). Natural gas distribution revenues are decoupled from their customer sales volumes, where applicable, which breaks the relationship between sales volumes and revenues recognized.

A summary of our retail electric GWh sales volumes and our firm natural gas Mcf sales volumes, ~~in million cubic feet (Mcf) and~~as well as percentage changes, is as follows:


	For the Three Months Ended September 30, 2016 Compared to 2015				For the Nine Months Ended September 30, 2016 Compared to 2015				For the Three Months Ended March 31, 2017 Compared to 2016
	Sales Volumes (GWh)		Percentage		Sales Volumes (GWh)		Percentage		Sales Volumes (GWh)		Percentage
Electric	2016	2015	Increase/(Decrease)		2016	2015	Increase/(Decrease)		2017	2016	Increase/(Decrease)
Traditional:
Residential	2,910	2,832	2.8	%	7,407	7,706	(3.9	)%	2,436	2,404	1.3	%
Commercial	4,525	4,583	(1.3	)%	12,376	12,615	(1.9	)%	3,939	3,990	(1.3	)%
Industrial	696	721	(3.5	)%	1,948	1,988	(2.0	)%	596	600	(0.7	)%
Total – Traditional	8,131	8,136	(0.1	)%	21,731	22,309	(2.6	)%	6,971	6,994	(0.3	)%

Decoupled:
Residential	3,398	3,245	4.7	%	8,750	9,108	(3.9	)%	2,988	2,943	1.5	%
Commercial	3,039	3,030	0.3	%	8,315	8,524	(2.5	)%	2,591	2,618	(1.0	)%
Industrial	776	795	(2.4	)%	2,170	2,233	(2.8	)%	622	664	(6.3	)%
Total – Decoupled	7,213	7,070	2.0	%	19,235	19,865	(3.2	)%	6,201	6,225	(0.4	)%
Total Sales Volumes	15,344	15,206	0.9	%	40,966	42,174	(2.9	)%	13,172	13,219	(0.4	)%


	For the Three Months Ended September 30, 2016 Compared to 2015				For the Nine Months Ended September 30, 2016 Compared to 2015				For the Three Months Ended March 31, 2017 Compared to 2016
	Sales Volumes (Mcf)		Percentage		Sales Volumes (Mcf)		Percentage		Sales Volumes (Mcf)		Percentage
Firm Natural Gas	2016	2015	Increase/(Decrease)		2016	2015	Increase/(Decrease)		2017	2016	Increase/(Decrease)
Traditional:
Residential	956	955	0.1	%	10,109	12,022	(15.9	)%	7,093	6,642	6.8	%
Commercial	2,350	2,310	1.7	%	13,864	15,578	(11.0	)%	8,409	7,976	5.4	%
Industrial	1,964	2,184	(10.1	)%	7,597	8,755	(13.2	)%	3,403	3,367	1.1	%
Total – Traditional	5,270	5,449	(3.3	)%	31,570	36,355	(13.2	)%	18,905	17,985	5.1	%

Decoupled:
Residential	1,308	1,531	(14.6	)%	13,848	17,078	(18.9	)%	10,185	9,309	9.4	%
Commercial	2,147	2,065	4.0	%	15,019	17,002	(11.7	)%	9,130	8,988	1.6	%
Industrial	990	977	1.3	%	4,163	4,670	(10.9	)%	1,709	1,854	(7.8	)%
Total – Decoupled	4,445	4,573	(2.8	)%	33,030	38,750	(14.8	)%	21,024	20,151	4.3	%
Special Contracts ⁽¹⁾	1,208	1,115	8.3	%	3,507	3,384	3.6	%	1,217	1,212	0.4	%
Total – Decoupled and Special Contracts	5,653	5,688	(0.6	)%	36,537	42,134	(13.3	)%	22,241	21,363	4.1	%
Total Sales Volumes	10,923	11,137	(1.9	)%	68,107	78,489	(13.2	)%	41,146	39,348	4.6	%


⁽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’~~customers' usage.

For the ~~third~~first quarter of ~~2016,~~2017, retail electric sales volumes at our electric utilities with a traditional rate structure (NSTAR Electric and PSNH) remained relatively unchanged, as compared to the ~~third~~first quarter of ~~2015. Favorable results due to~~2016. Colder weather in the third quarter of 2016 were offset by lower customer usage driven by the impact of increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, which resulted in flat traditional retail electric sales volumes. For the first nine months of 2016, retail electric sales volumes at our electric utilities with a traditional rate structure were lower,March 2017, as compared to ~~the first nine months of 2015, due primarily to lower customer usage driven~~March 2016, was offset by the ~~impact of increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, and the impact of warmer than normal~~milder weather in the first quarter of 2016 throughout those service territories, as compared to the much colder than normal temperatures in the first quarter of 2015. Heating degree days for the first nine months 2016 were 18.4 percent lower in the Boston metropolitan areaJanuary and ~~17.9 percent lower in New Hampshire,~~February 2017, as compared to the same ~~period~~periods in ~~2015.~~ 2016, which resulted in an overall slight decrease in sales volumes.

On January 28, 2016, Eversource received approval of a three-year energy efficiency plan in Massachusetts, which includes recovery of LBR at NSTAR Electric until it is operating under a decoupled rate structure. NSTAR Electric earns LBR related to reductions in sales volume as a result of successful energy efficiency programs. LBR is recovered from retail customers through current rates. NSTAR Electric recognized LBR of ~~$17.4 million and $44.1~~$17.2 million in the ~~third~~first quarter ~~and first nine months~~ of ~~2016, respectively,~~2017, compared to ~~$19 million and $46.7~~$12.9 million in the ~~third~~first quarter ~~and first nine months~~ of ~~2015, respectively.~~2016.

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 the ~~third~~first quarter of ~~2016,~~2017, our consolidated firm natural gas sales volumes were ~~lower, as compared to the third quarter of 2015. Consolidated firm natural gas sales volumes were much lower in the first nine months of 2016,~~higher, as compared to the first ~~nine months of 2015. The first nine months of 2016 firm natural gas sales volumes were negatively impacted by warmer than normal weather in the first~~ quarter of ~~2016, as compared to the much colder than normal temperatures in the first quarter of 2015, throughout our natural gas service territories.~~2016. Heating degree days for the first ~~nine months~~quarter of ~~2016~~2017 were ~~16.7~~4.0 percent ~~lower~~higher in Connecticut, as compared to the same period in ~~2015.~~2016.

Liquidity

Consolidated: Cash and cash equivalents totaled ~~$40.1~~$45.8 million as of ~~September 30, 2016,~~March 31, 2017, compared with ~~$23.9~~$30.3 million as of December 31, ~~2015.~~2016.

Long-Term Debt Issuances: In March 2017, Eversource parent issued $300 million of 2.75 percent Series K Senior Notes, due to mature in 2022. The proceeds, net of issuance costs, were used to repay short-term borrowings under the Eversource parent commercial paper program. Also in March 2017, CL&P issued $300 million of 3.20 percent 2017 Series A First and Refunding Mortgage Bonds due to mature in 2027. The proceeds, net of issuance costs, were used to repay short-term borrowings.

Long-Term Debt Repayments: In March 2017, CL&P repaid at maturity the $150 million of 5.375 percent 2007 Series A First and Refunding Mortgage Bonds, using short-term borrowings.

Cash Flows: Cash flows provided by operating activities totaled ~~$1.65 billion~~$436.5 million in the first ~~nine months~~quarter of ~~2016,~~2017, compared with ~~$1.35 billion~~$500.0 million in the first ~~nine months~~quarter of ~~2015.~~2016. The ~~increase~~decrease in operating cash flows was due primarily to ~~an increase~~$211.9 million in lower income tax refunds as a result of the impact of the December 2015 legislation that extended tax bonus depreciation. That legislation extended the accelerated deduction of depreciation to businesses from 2015 to 2019, and also resulted in a refund of approximately $275 million we received in the first quarter of 2016. Partially offsetting this unfavorable impact was the timing of regulatory recoveries, which primarily ~~at NSTAR Electric, due~~related to ~~collections from customers~~customer billings in excess of purchased power costs, ~~a $94.8 million net favorable impact due to the change in income tax payments made, or refunds received, a decrease of $41 million in Pension and PBOP plan cash contributions~~ and the timing of ~~payments related to~~collections on our accounts ~~payable. Partially offsetting these favorable impacts was the timing of collections and payments related to our working capital items.~~receivable.

~~Credit Ratings:~~ On July 6, 2016, Fitch upgraded the corporate credit ratings by one level and changed the outlooks to stable from positive for CL&P, PSNH and WMECO. Also on July 6, 2016, Fitch changed the outlook on Eversource parent from stable to positive. On July 12, 2016, S&P changed its outlook on Eversource and its subsidiaries from stable to positive. On July 19, 2016, Moody’s upgraded PSNH’s corporate credit rating by one level and changed the outlook from positive to stable.

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



	~~Moody’s~~		~~S&P~~		~~Fitch~~
	~~Current~~	~~Outlook~~	~~Current~~	~~Outlook~~	~~Current~~	~~Outlook~~
~~Eversource Parent~~	~~Baa1~~	~~Stable~~	A	~~Positive~~	~~BBB+~~	~~Positive~~
~~CL&P~~	~~Baa1~~	~~Stable~~	A	~~Positive~~	A-	~~Stable~~
~~NSTAR Electric~~	A2	~~Stable~~	A	~~Positive~~	A	~~Stable~~
~~PSNH~~	A3	~~Stable~~	A	~~Positive~~	A-	~~Stable~~
~~WMECO~~	A2	~~Stable~~	A	~~Positive~~	A-	~~Stable~~

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



	~~Moody’s~~		~~S&P~~		~~Fitch~~
	~~Current~~	~~Outlook~~	~~Current~~	~~Outlook~~	~~Current~~	~~Outlook~~
~~Eversource Parent~~	~~Baa1~~	~~Stable~~	A-	~~Positive~~	~~BBB+~~	~~Positive~~
~~CL&P~~	A2	~~Stable~~	A+	~~Positive~~	A+	~~Stable~~
~~NSTAR Electric~~	A2	~~Stable~~	A	~~Positive~~	A+	~~Stable~~
~~PSNH~~	A1	~~Stable~~	A+	~~Positive~~	A+	~~Stable~~
~~WMECO~~	A2	~~Stable~~	A	~~Positive~~	A	~~Stable~~

On ~~September 7, 2016,~~February 2, 2017, our Board of Trustees approved a common share dividend of $0.475 per share, payable on March 31, 2017 to shareholders of record as of March 2, 2017. In the first quarter of 2017, we paid cash dividends on common shares of $150.5 million, compared with $141.2 million in the first quarter of 2016. On May 3, 2017, our Board of Trustees approved a common share dividend payment of ~~$0.445~~$0.475 per share, ~~which was paid~~payable on ~~September~~June 30, ~~2016~~2017 to shareholders of record as of ~~September 19, 2016. In the first nine months of 2016, we paid cash dividends on common shares of $423.5 million, compared with $397.4 million in the first nine months of 2015.~~May 31, 2017.

In the first ~~nine months~~quarter of ~~2016,~~2017, CL&P, NSTAR Electric, PSNH, and WMECO paid ~~$149.7~~$49.6 million, ~~$278.3~~$46.5 million, ~~$58.2~~$18.5 million, and ~~$28.5~~$9.5 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 the first ~~nine months~~quarter of ~~2016,~~2017, investments for Eversource, CL&P, NSTAR Electric, PSNH, and WMECO were ~~$1.36 billion, $438.5~~$523.6 million, ~~$327.7~~$181.6 million, ~~$215.8~~$132.1 million, $75.3 million, and ~~$104.8~~$32.7 million respectively.

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 ~~$1.43 billion in the first nine months of 2016, compared to $1.26 billion in the first nine months of 2015. These amounts included $87.1 million and $58.6~~$446.4 million in the first ~~nine months~~quarter of ~~2016~~2017, compared to $368.5 million in the first quarter of 2016. These amounts included $21.5 million and ~~2015,~~$24.0 million in the first quarter of 2017 and 2016, respectively, 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 Partners, LP (Spectra)~~Enbridge, Inc. ("Enbridge") and National Grid plc ~~(National Grid)~~("National Grid"), through Algonquin Gas Transmission, LLC ~~(AGT)~~("AGT"). ~~The Project~~

~~will~~This project is expected to enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes and ~~will~~is expected to include two new LNG storage tanks and liquefaction and vaporization facilities in Acushnet, Massachusetts that ~~will~~are currently expected to be connected to the Algonquin natural gas pipeline. ~~The Project~~Access Northeast 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~~Enbridge each own a 40 percent interest in the ~~Project,~~project, with the remaining 20 percent interest owned by National Grid. The ~~total projected cost for both the pipeline and the LNG storage facilities is expected to be approximately $3 billion, with projected in-service dates commencing in November 2018. The Project~~project is subject to FERC and other federal and state regulatory approvals. Its initial proposed configuration was expected to cost approximately $3 billion to construct, with Eversource Energy's investment share at approximately $1.2 billion. As of March 31, 2017, we have invested $31.1 million in this project.

As part of the Project’s development, AGT sought to secure long-term natural gas transmission capacity contracts with many of the electric distribution companies (EDCs) of New England. In Connecticut, on June 2, 2016, the DEEP issued an RFP for natural gas pipeline capacity and storage. Proposals were submitted on June 29, 2016. On October 25, 2016, the DEEP canceled this RFP process without prejudice. The DEEP retains its authority to issue future RFPs to procure natural gas resources for the purpose of providing more reliable electric service for the benefit of the Connecticut customers and to meet the state’s energy and environmental goals and policies.

On June 30, 2016, a subsidiary of National Grid filed with the Rhode Island Public Utilities Commission (RIPUC) seeking approval of its contract with AGT for natural gas pipeline capacity and storage. The RIPUC has placed a stay on the docket and asked National Grid for a status update in January 2017. On September 14, 2016, the Maine PUC issued an order to move forward with a contract with AGT for natural gas pipeline capacity, contingent upon the participation by EDCs in other New England states.

In late 2015 and early 2016, NSTAR Electric, WMECO and a subsidiary of National Grid filed with the Massachusetts DPU seeking approval of contracts with AGT for natural gas pipeline capacity and storage. The DPU had determined in 2015 that it had authority to approve such contracts if they were found to be in the public interest. On August 17, 2016, the Massachusetts Supreme Judicial Court vacated the DPU’s 2015 order, holding that the state’s electric utility restructuring statutes precluded the DPU from approving contracts by EDCs for natural gas capacity.

On February 18, 2016, PSNH filed with the NHPUC seeking approval of its contract with AGT for natural gas pipeline capacity and storage. On October 6, 2016, contrary to a 2015 recommendation from its staff, the NHPUC ruled that it did not have authority to approve such contracts under the state’s electric utility restructuring statutes.

Enbridge, Eversource ~~Spectra~~ and National Grid are currently ~~reviewing~~evaluating a series of options surrounding ~~the Project, with respect to the impact of the decisions from both the Massachusetts Supreme Judicial Court~~Access Northeast, including state infrastructure legislation changes and ~~the NHPUC,~~LDC contracts, in order to help bring needed additional natural gas ~~transmission~~pipeline and storage capacity to New England. The timing, configuration and cost of the Project could change, depending on the outcome of the potential options selected. At this time, we cannot predict the outcome of the potential options selected. At this time, we cannot predict the outcome of the potential options selected and, asAs a result, the ~~potential impacts on our financial position, results~~final design, cost, and in-service date of ~~operations, or cash flows.~~Access Northeast will continue to be refined.

Bay State Wind: Bay State Wind is a proposed off-shore wind project being jointly developed by Eversource and Denmark-based DONG Energy. Bay State Wind will be located in a 300-square-mile area approximately 15 to 25 miles south of Martha's Vineyard that has the ultimate potential to generate more than 2,000 MW of energy. Both Eversource and DONG Energy hold a 50 percent ownership interest in Bay State Wind. In August 2016, Massachusetts passed clean energy legislation that requires EDCs to jointly solicit RFPs and enter into long-term contracts for off-shore wind, creating RFP opportunities for projects like Bay State Wind. The initial RFP, which is legislatively required to be for no less than 400 MW of off-shore wind, is due to be released by June 30, 2017, and Bay State Wind will be bid into that RFP.

Electric Transmission Business:

Our consolidated electric transmission business capital expenditures increased by ~~$37.1~~$29.3 million in the first ~~nine months~~quarter of ~~2016,~~2017, as compared to the first ~~nine months~~quarter of ~~2015.~~2016. A summary of electric transmission capital expenditures by company is as follows:

For the Nine Months Ended September 30,
(Millions of Dollars) 2016 2015
CL&P $ 211.8
$ 146.9
NSTAR Electric 162.6
158.9
PSNH 80.2
115.2
WMECO 75.7
72.9
NPT 28.4
27.7
Total Electric Transmission Segment $ 558.7
$ 521.6

~~GHCC~~: The Greater Hartford Central Connecticut (GHCC) solutions, which have been approved by ISO-NE, consist of 27 projects with an expected investment of approximately $350 million that are expected to be placed in service from 2016 through 2018. Seven projects have been placed in service, and 8 projects are in active construction. As of September 30, 2016, CL&P had capitalized $93 million in costs associated with GHCC.



	For the Three Months Ended March 31,
(Millions of Dollars)	2017		2016
CL&P	$	79.9	$	63.4
NSTAR Electric	39.2		31.7
PSNH	21.6		19.6
WMECO	18.6		18.0
NPT	9.7		7.0
Total Electric Transmission Segment	$	169.0	$	139.7

Northern Pass: Northern Pass is ~~Eversource’s~~NPT's planned ~~HVDC~~high-voltage direct-current ("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)~~("EIS") for Northern Pass representing a key milestone in the permitting process. The DOE completed the comment period on the draft EIS on April 4, 2016, and is expected to issue the final EIS in the ~~first~~third quarter of 2017.

On August 18, 2015, NPT announced the Forward NH Plan, which is expected to deliver substantial energy cost savings and other benefits to New Hampshire, including a commitment to ~~allocate~~contribute $200 million to projects associated with economic development, tourism, community betterment and clean energy innovations to benefit the state of New Hampshire.

On June 10, 2016, Northern Pass executed a settlement agreement with the NHPUC Staff regarding its petition to operate as a public utility once the project is fully permitted. On October 14, 2016, in an important foundational order for the Northern Pass project, the NHPUC approved the settlement agreement and granted NPT public utility status, conditioned on project approval. Additionally, on June 28, 2016, as part of theThe Forward NH Plan also included a commitment by PSNH ~~filed~~to secure a power purchase agreement ~~(PPA)~~("PPA") with HQ to ensure that customers receive their load share of the low cost, clean energy to be delivered over that transmission line. On June 28, 2016, PSNH filed the executed PPA with the ~~NHPUC. The PPA, combined with~~NHPUC for approval. On March 27, 2017, the ~~Forward NH Plan, is expected to deliver over $1 billion~~NHPUC dismissed PSNH's petition for approval of ~~energy cost savings and other benefits over~~ the ~~contract term to New Hampshire customers.~~PPA. PSNH had requested suspension or reconsideration of that decision but on April 20, 2017, the request was denied by the NHPUC. The Forward NH Plan and the PPA are both commitments that are contingent upon the Northern Pass transmission line going into commercial operation.

On October 14, 2016, the NHPUC approved a settlement agreement between NPT and the NHPUC staff and granted NPT public utility status, conditional on final project permitting.

The Society for the Protection of New Hampshire Forests ("SPNHF") filed a lawsuit against NPT in November 2015 alleging that NPT does not have the right to install underground transmission lines in the public highway right of way without the permission of the abutting landowners, such as the SPNHF. On January 31, 2017, the New Hampshire Supreme Court upheld a lower court's ruling confirming that NPT has the right to install underground transmission lines along and beneath public highways in New Hampshire with approval of the New Hampshire Department of Transportation.

The New Hampshire Site Evaluation Committee ~~(NH SEC) is currently in process of~~("NH SEC") commenced hearings for formal ~~siting. The NH SEC~~siting on April 13, 2017 and is expected to issue an order on ~~NPT~~Northern Pass no later than September ~~2017 and the project~~30, 2017. The DOE is expected to ~~be operational~~act on a Presidential Permit for Northern Pass after the final NH SEC order is released and is expected to issue an approval before the end of 2017. Northern Pass has been targeted for completion by the end of 2019. ~~On January 28,~~

In August 2016, ~~NPT~~Massachusetts enacted clean energy legislation that requires EDCs to jointly solicit proposals and enter into long-term contracts for energy, such as hydropower. The RFP was issued on March 31, 2017, and Northern Pass will be bid into ~~the three-state Clean Energy~~that 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 Condition and Results of Operations.~~late July 2017.

Greater Boston Reliability ~~Solutions~~Solution: In February 2015, ISO-NE selected ~~Eversource’s and National Grid’s proposed~~the Greater Boston and New Hampshire Solution ~~(Solution)~~(the "Solution"), proposed by Eversource and National Grid, to satisfy the requirements identified in the Greater Boston study. The Solution consists of a portfolio of ~~some 40~~ electric transmission upgrades covering southern New Hampshire and northern Massachusetts in the Merrimack Valley and continuing into the greater Boston metropolitan area, of which 2728 are in ~~Eversource’s~~Eversource's service territory. The NH SEC issued its written order approving the New Hampshire upgrades on October 4, 2016. We are currently pursuing the necessary regulatory and siting application approvals in Massachusetts. Construction has also begun on several ~~of the~~ smaller projects not requiring siting approval. All upgrades are expected to be completed by the end of 2019. We estimate our portion of the investment in the Solution will be approximately ~~$565~~$560 million, of which ~~approximately $91~~$146.4 million has been capitalized through ~~September 30, 2016.~~March 31, 2017.

GHCC: The Greater Hartford Central Connecticut ("GHCC") projects, which have been approved by ISO-NE, consist of 27 projects with an expected investment of approximately $350 million that are expected to be placed in service through 2018. Twelve projects have been placed in service, and eleven projects are in active construction. As of March 31, 2017, CL&P had capitalized $141.6 million in costs associated with GHCC.

Seacoast Reliability Project: On April 12, 2016, PSNH filed a siting application with the NH SEC for the Seacoast Reliability Project, a 13-mile, 115kV transmission line within several New Hampshire communities, which proposes to use a combination of overhead, underground and underwater line design to help meet the growing demand for electricity in the Seacoast region. In June 2016, the NH SEC accepted our application as complete and we expect the NH SEC decision by ~~mid-2017.~~late 2017. This project is expected to be completed by the end of 2018. We now estimate our investment in this project will be approximately ~~$77~~$84 million, of which ~~approximately $11~~$15.4 million has been capitalized through ~~September 30, 2016.~~March 31, 2017.

Distribution Business:

A summary of distribution capital expenditures is as follows:


	For the Nine Months Ended September 30,															For the Three Months Ended March 31,
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		WMECO			Total Electric		Natural Gas		Total Electric and Natural Gas Distribution Segment		CL&P		NSTAR Electric		PSNH		WMECO			Total Electric		Natural Gas		Total Electric and Natural Gas Distribution Segment
2017
Basic Business																$	42.9	$	30.1	$	17.8	$	5.2		$	96.0	$	15.8	$	111.8
Aging Infrastructure																40.6		14.6		19.4		4.3			78.9		29.0		107.9
Load Growth ⁽¹⁾																9.5		15.8		4.3		(2.3		)	27.3		6.0		33.3
Total Distribution																93.0		60.5		41.5		7.2			202.2		50.8		253.0
Generation																—		0.3		2.3		0.3			2.9		—		2.9
Total Electric and Natural Gas Distribution Segment																$	93.0	$	60.8	$	43.8	$	7.5		$	205.1	$	50.8	$	255.9

2016
Basic Business	$	127.0	$	87.7	$	46.8	$	10.7		$	272.2	$	48.9	$	321.1	$	39.1	$	24.0	$	15.1	$	3.4		$	81.6	$	12.6	$	94.2
Aging Infrastructure	97.4		57.8		61.9		17.6			234.7		103.0		337.7		26.5		12.5		14.4		4.4			57.8		19.2		77.0
Load Growth	31.9		48.1		11.8		(2.5		)	89.3		28.3		117.6		9.0		14.2		3.5		0.5			27.2		6.0		33.2
Total Distribution	256.3		193.6		120.5		25.8			596.2		180.2		776.4		74.6		50.7		33.0		8.3			166.6		37.8		204.4
Generation	—		—		8.5		—			8.5		—		8.5		—		—		0.4		—			0.4		—		0.4
Total Electric and Natural Gas Distribution Segment	$	256.3	$	193.6	$	129.0	$	25.8		$	604.7	$	180.2	$	784.9	$	74.6	$	50.7	$	33.4	$	8.3		$	167.0	$	37.8	$	204.8

2015
Basic Business	$	87.8	$	75.2	$	37.8	$	12.2		$	213.0	$	35.1	$	248.1
Aging Infrastructure	120.0		69.8		33.9		13.5			237.2		71.8		309.0
Load Growth	29.6		30.5		15.8		4.6			80.5		25.9		106.4
Total Distribution	237.4		175.5		87.5		30.3			530.7		132.8		663.5
Generation	—		—		15.9		—			15.9		—		15.9
Total Electric and Natural Gas Distribuion Segment	$	237.4	$	175.5	$	103.4	$	30.3		$	546.6	$	132.8	$	679.4

⁽¹⁾ For the three months ended March 31, 2017, WMECO had $4.7 million of total contributions in aid of construction, which was a credit to capital expenditures for the period.

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.

For the natural gas distribution segment, basic business addresses daily operational needs including meters, pipe relocations due to public works projects, vehicles, and tools. Aging infrastructure projects seek to improve the

reliability of the system through enhancements related to cast iron and bare steel replacement of main and services, corrosion mediation, and station upgrades. Load growth reflects growth in existing service territories including new developments, installation of services, and expansion.

The natural gas distribution ~~segment’s~~segment's capital spending program increased by ~~$47.4~~$13.0 million in the first ~~nine months~~quarter of ~~2016,~~2017, as compared to the first ~~nine months~~quarter of ~~2015,~~2016, as a result of ~~an increase~~the Hopkinton Liquefier Replacement project. The total project cost is estimated to be approximately $170 million and is expected to be placed in ~~the replacement of aging pipeline, upgrades to our LNG facilities, and the favorable weather conditions~~service in ~~2016 allowing for more capital spending on replacement and customer expansion.~~late 2019.

FERC Regulatory Matters

FERC ROE Complaints: Four separate complaints have been filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other ~~parties. Each complaint challenges~~parties (collectively the ~~NETOs’ previous~~"Complainants"). In each of the first three complaints, the Complainants challenged the NETOs' base ROE of 11.14 percent ~~or current~~that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the 15-month complaint periods arising from the separate complaints. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE of 10.57 percent and ~~seeks~~the maximum ROE for transmission incentive ("incentive cap") of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

In response to ~~reduce~~appeals of the FERC decision in the first complaint filed by the NETOs and the Complainants, the D.C. Circuit Court of Appeals (the "Court") issued a decision on April 14, 2017 vacating and remanding the FERC's decision. The Court found that the FERC failed to make an explicit finding that the prior 11.14 percent base ROE was unjust and unreasonable, as required under Section 206 of the Federal Power Act, before it ~~both~~could set a new base ROE. The Court also found that the FERC did not provide a rational connection between the record evidence and its decision to select the midpoint of the upper half of the zone of reasonableness for the new base ROE.

A summary of the four separate ~~15-month complaint periods~~complaints and ~~prospectively.~~ the base ROEs pertinent to those complaints are as follows:



Complaint	15-Month Time Period of Complaint (Beginning as of Complaint Filing Date)	Original Base ROE Authorized by FERC at Time of Complaint Filing Date ⁽¹⁾	Base ROE Subsequently Authorized by FERC for First Complaint Period and also Effective from October 16, 2014 through April 14, 2017 ⁽¹⁾	Reserve (Pre-Tax and Excluding Interest) as of March 31, 2017 (in millions)		FERC ALJ Recommendation of Base ROE on Second and Third Complaints (Issued March 22, 2016)
First	10/1/2011 - 12/31/2012	11.14%	10.57%	$—	⁽²⁾	N/A
Second	12/27/2012 - 3/26/2014	11.14%	N/A	39.1	⁽³⁾	9.59%
Third	7/31/2014 - 10/30/2015	11.14%	10.57%	—		10.90%
Fourth	4/29/2016 - 7/28/2017	10.57%	10.57%	—		N/A

⁽¹⁾The total ROE between October 1, 2011 and October 15, 2014 was within a range of 11.14 percent to 13.1 percent. In 2014, as a result of a FERC ~~ordered a 10.57~~order, the incentive cap was set at 11.74 percent ~~base ROE~~ for the first complaint period and ~~prospectively~~also effective from October 16, 2014 through April 14, 2017.

⁽²⁾ CL&P, NSTAR Electric, PSNH and ~~that a utility’s total or maximum ROE for any incentive projects shall not exceed the top of the new zone of reasonableness, which was set at 11.74 percent. We~~WMECO have refunded all amounts associated with the first complaint ~~period.~~

~~The Company has recorded reserves across the complaint periods~~period, totaling $38.9 million (pre-tax and excluding interest) at ~~its electric subsidiaries. In the first nine months of 2015, the Company recognized an after-tax charge to earnings (excluding interest) of $12.4~~Eversource (including $22.4 million ~~of which $7.9 million was recorded~~ at CL&P, ~~$1.4~~$8.4 million at NSTAR Electric, ~~$0.6~~$2.8 million at PSNH, and ~~$2.5~~$5.3 million at ~~WMECO.~~

On March 22, 2016, the FERC ALJ issued an initial decision on the second and third complaints. For the second complaint period, the FERC ALJ recommended a zone of reasonableness of 7.12 percent to 10.42 percent and a base ROE of 9.59 percent. For the third complaint period, the FERC ALJ recommended a zone of reasonableness of 7.04 percent to 12.19 percent and a base ROE of 10.90 percent. The FERC ALJ also affirmed that the maximum ROE for transmission incentive projects should be the top of the zone of reasonableness. The NETOs filed briefs on April 21, 2016, in which the NETOs identified corrections and requested changes that should be made to the FERC ALJ’s recommendations. A final FERC order is expected in late 2016 or early 2017. The final FERC order will determineWMECO), reflecting both the base ROE and incentive cap prescribed by the ~~maximum ROE for transmission incentive projects for the two complaint periods.~~ FERC order.

~~We have not recorded any additional reserves to reflect~~⁽³⁾ The reserve represents the difference between the ROEs ~~recommended in~~billed during the ~~FERC ALJ initial decision. We do not believe any ROE outcome is more likely than the ROEs used to record our current reserves (a base ROE of 10.57 percent~~second complaint period and a maximum ROE for transmission incentive projects of 11.74 percent). We are unable to predict the outcome of the final FERC order on the second and third complaints, and therefore, we believe that our current ROEs and reserves are appropriate at this time.

~~The impact of a 10 basis point change to our existing base ROE of~~ 10.57 percent would affect Eversource’s after-tax earnings by approximately $3 million for each of the 15-month second and third complaint periods. If we adjusted our reserves based on the recommendations in the FERC ALJ initial decision (for both the base ROE and ~~maximum ROE~~11.74 percent incentive cap. The reserve was $21.4 million for ~~transmission incentive projects)~~CL&P, $8.5 million for NSTAR Electric, $3.1 million for PSNH, and $6.1 million for WMECO as of March 31, 2017.

At this time, the Company cannot reasonably estimate a range of gain or loss for the complaint proceedings. The Court decision did not provide a reasonable basis for a change to the March 31, 2017 reserve balance of $39.1 million (pre-tax and excluding interest) for the second complaint period, and ~~third complaints, then it would result in an after-tax increase~~the Company has not changed its reserves or recognized ROEs for any of ~~approximately $34 million and an after-tax decrease of approximately $8 million, respectively, to our existing reserves.~~the complaint periods.

~~For the~~fourth complaint, filed April 29, 2016, certain municipal utilities claimed the current base ROE of 10.57 percent and the incentive cap of 11.74 percent are unjust and unreasonable. The NETOs answered on June 3, 2016 and requested that FERC dismiss the complaint. On September 20, 2016, FERC issued an order establishing hearing and settlement judge procedures~~and set a 15-month complaint period beginning April 29, 2016. We~~Management cannot at this time predict the ultimate ~~outcome~~effect of ~~this proceeding~~the Court decision on any of the complaint periods or the estimated impacts on the financial position, results of operations or cash flows of Eversource, CL&P, NSTAR Electric, PSNH and WMECO. A

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

FERC ~~ALJ initial~~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, to allow for competition. ISO-NE and the NETOs, including CL&P, NSTAR Electric, PSNH and WMECO, made compliance filings to address this policy, which included exemption from competition for certain transmission solutions previously evaluated by ISO-NE, and the NETOs' rights to retain use and control of existing right of ways. This compliance was accepted by the FERC on December 14, 2015. At the same time, the NETOs filed an appeal to the D.C. Circuit Court of Appeals, challenging FERC's removal of the right of first refusal. State regulators also filed an appeal, challenging the FERC's determination that ISO-NE should select public policy transmission projects after a competitive process. On April 18, 2017, the D.C. Circuit Court of Appeals issued a decision ~~could be received~~rejecting both challenges.

NSTAR Electric and WMECO Merger FERC Filings: On January 13, 2017, Eversource made two filings with FERC related to the proposed merger of WMECO into NSTAR Electric with an anticipated effective date of January 1, 2018. One filing requests FERC approval of the merger, and the other filing requests FERC approval of NSTAR Electric's assumption of WMECO's short-term debt obligations. The FERC approved the merger on March 2, 2017 and will act on the assumption of debt filing later in 2017.

Regulatory Developments and Rate Matters

~~General:~~

~~Clean Energy RFP~~: Pursuant to clean energy goals established in three New England states (Connecticut, Massachusetts and Rhode Island), in November 2015, the DEEP and the Massachusetts and Rhode Island EDCs, including NSTAR Electric and WMECO, issued an RFP for clean energy resources (including Class I renewable generation and large hydroelectric generation) to a wide range of potentially interested bidders. The RFP solicited offers for clean energy and the transmission to deliver that energy to the three states. In late January 2016, bidders submitted project proposals, among which were the Northern Pass and Clean Energy Connect projects. On October 24, 2016, Eversource was notified that neither project was selected.

The Company is currently placing efforts on the next round of contracting opportunities, which it believes both NPT and the Clean Energy Connect projects would meet the legislative requirements. In August 2016, Massachusetts enacted legislation that requires electric distribution companies to jointly solicit RFPs and enter into long-term contracts for large-scale hydro projects. The law requires an RFP to take place in the spring of 2017. For further information on this legislation, see “Legislative and Policy Matters - Massachusetts” in this “~~Management’s Discussion and Analysis of Financial Condition and Results of Operations.~~”

Electric and Natural Gas Base Distribution Rates:

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. Other than as described below, for the first ~~nine months~~quarter of ~~2016,~~2017, changes made to the Regulated companies’ rates did not have a material impact on their earnings, financial position, or cash flows. For further information, see “Financial Condition and Business Analysis – Regulatory Developments and Rate Matters” included in Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” of the Eversource ~~2015~~2016 Form 10-K.

Connecticut:

On April 20, 2017, PURA approved the joint request of CL&P, the Connecticut Office of Consumer Counsel and the Connecticut Attorney General to amend the deadline to establish new electric distribution rates in the 2012 Connecticut merger settlement agreement from "no later than December 1, 2017" to "no later than July 1, 2018".

Massachusetts:

~~October 2016 DPU Storm Order~~Clean Energy RFP:: On ~~October 7,~~March 31, 2017, pursuant to comprehensive energy legislation, "An Act to Promote Energy Diversity," which became law in 2016, the ~~DPU~~Massachusetts EDCs, including NSTAR Electric and WMECO, and the DOER issued a joint RFP for 9.45 terawatt hours of clean energy per year, such as hydropower, land-based wind or solar. The RFP seeks proposals for long-term contracts of 15 to 20 years to provide the state's electric distribution companies with clean energy generation. The proposal submission due date is July 27, 2017. Contracts will be selected in January 2018, with an expectation to submit executed long-term contracts to the DPU for final approval in April 2018. Northern Pass will be bid into the RFP.

NSTAR Electric and WMECO Rate Case: On January 17, 2017, NSTAR Electric and WMECO jointly filed an application (the "Joint Applicants") with the DPU for approval of a combined $96 million increase in base distribution rates, effective January 1, 2018. As part of this filing, the Joint Applicants are presenting a grid-wise performance plan, including the implementation of a performance-based rate-making mechanism in conjunction with a grid modernization base commitment of $400 million in incremental capital investment over a period of five years, commencing January 1, 2018. In addition, the Joint Applicants are proposing to streamline and align rate classifications between NSTAR Electric and WMECO, and requesting a revenue decoupling rate mechanism for NSTAR Electric. WMECO has a revenue decoupling mechanism in place. The DPU will also be reviewing the proposed merger of NSTAR Electric and WMECO as part of the rate case. A final decision ~~on WMECO’s storm cost filing that sought~~from the DPU is expected in late 2017, with new rates anticipated to recover $27 million of storm restoration costs associated with the October 2011 snowstorm and Storm Sandy in 2012. The DPU approved the majority of the costs, with the disallowed amounts and other items included in a filed motion for reconsideration.be effective January 1, 2018.

New Hampshire:

Generation ~~Asset Sale~~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)~~"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. Under the terms of the Agreement, PSNH agreed to divest its generation assets, subject to NHPUC approval. The Agreement provided for a resolution of issues pertaining to ~~PSNH’s~~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 agreed to forego recovery of $25 million of the 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 the first nine months of 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.~~

On July 1, 2016, the NHPUC approved the Agreement in an order that, among other things, instructs PSNH to begin the process ~~to divest~~of divesting its generation assets. The NHPUC selected an auction adviser to assist with the divestiture, and athe final plan and auction process ~~will be determined~~were approved by the NHPUC in November 2016. An intervening appeal alleging that the ~~fourth quarter~~auction process and schedule were unreasonable was rejected by the New Hampshire Supreme Court in February 2017. In late March 2017, the formal divestiture process began. We continue to believe the assets will be sold by the end of ~~2016.~~2017.

As of March 31, 2017, PSNH's energy service rate base subject to divestiture was approximately $620 million. This rate base will be reduced by the amount of the sales proceeds from the generation assets that are divested and sold. 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 recoveries in rates billed to PSNH’s customers.~~

~~We believe that~~ full recovery of ~~PSNH’s~~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 via bonds that will be secured by a non-bypassable charge or through recoveries in future ~~rates.~~

~~As of September 30, 2016, PSNH’s energy service rate base was approximately $640 million. This rate base will be reduced by the amount of generation assets that are divested.~~

~~Legislative and Policy Matters~~

~~Massachusetts:~~

~~On August 8, 2016, in conjunction with efforts~~rates billed to shape comprehensive energy legislation, “An Act to Promote Energy Diversity” became law in Massachusetts, which requires electric distribution companies to jointly solicit RFPs and enter into 15- to 20-year contracts for at least 1,600 MW of offshore wind and up to an additional 1,200 MW of hydropower or other renewable sources, such as land-based wind or solar, provided that reasonable proposals have been received.PSNH's customers.

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 communicates to and discusses with the Audit Committee of our Board of Trustees significant matters relating to critical accounting policies. Our critical accounting policies that we believed were the most critical in nature were reported in the Eversource ~~2015~~2016 Form 10-K. There have been no material changes with regard to these critical accounting policies.

Other Matters

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

Contractual Obligations and Commercial Commitments: There have been no material contractual obligations identified and no material changes with regard to the contractual obligations and commercial commitments previously disclosed in the Eversource ~~2015~~2016 Form 10-K.

Web Site: Additional financial information is available through our website at www.eversource.com. We make available through our website a link to the ~~SEC’s~~SEC's EDGAR website (http://www.sec.gov/edgar/searchedgar/companysearch.html), at which site ~~Eversource’s,~~Eversource's, CL~~&P’s,~~&P's, NSTAR ~~Electric’s, PSNH’s~~Electric's, PSNH's and ~~WMECO’s~~WMECO's combined Annual Reports on Form 10-K, combined Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to those reports may be reviewed. Information contained on the ~~Company’s~~Company's website or that can be accessed through the website is not incorporated into and does not constitute a part of this combined Quarterly Report on Form 10-Q.

RESULTS OF OPERATIONS – EVERSOURCE ENERGY AND SUBSIDIARIES

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for Eversource for the three ~~and nine~~ months ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~ included in this combined Quarterly Report on Form 10-Q:


	For the Three Months Ended September 30,										For the Nine Months Ended September 30,									For the Three Months Ended March 31,
(Millions of Dollars)	2016		2015			Increase/(Decrease)			Percent		2016		2015		Increase/(Decrease)			Percent		2017		2016		Increase/ (Decrease)			Percent
Operating Revenues	$	2,039.7	$	1,933.1		$	106.6		5.5	%	$	5,862.5	$	6,263.6	$	(401.1	)	(6.4	)%	$	2,105.1	$	2,055.6	$	49.5		2.4	%
Operating Expenses:
Purchased Power, Fuel and Transmission	665.8		702.6			(36.8		)	(5.2	)	2,001.9		2,549.8		(547.9		)	(21.5	)	753.6		754.9		(1.3		)	(0.2	)
Operations and Maintenance	324.7		327.3			(2.6		)	(0.8	)	965.6		977.3		(11.7		)	(1.2	)	330.3		320.1		10.2			3.2
Depreciation	181.3		167.9			13.4			8.0		531.8		495.4		36.4			7.3		186.8		174.0		12.8			7.4
Amortization of Regulatory Assets/(Liabilities), Net	43.9		(16.8		)	60.7			(a)		56.2		42.6		13.6			31.9
Amortization of Regulatory Assets, Net																				24.0		21.0		3.0			14.3
Energy Efficiency Programs	149.1		132.1			17.0			12.9		406.0		380.6		25.4			6.7		146.2		137.2		9.0			6.6
Taxes Other Than Income Taxes	165.0		150.8			14.2			9.4		479.2		439.2		40.0			9.1		155.2		159.9		(4.7		)	(2.9	)
Total Operating Expenses	1,529.8		1,463.9			65.9			4.5		4,440.7		4,884.9		(444.2		)	(9.1	)	1,596.1		1,567.1		29.0			1.9
Operating Income	509.9		469.2			40.7			8.7		1,421.8		1,378.7		43.1			3.1		509.0		488.5		20.5			4.2
Interest Expense	99.9		92.5			7.4			8.0		298.6		279.6		19.0			6.8		103.4		98.2		5.2			5.3
Other Income, Net	13.6		5.2			8.4			(a)		23.7		23.9		(0.2		)	(0.8	)	13.6		2.0		11.6			(a)
Income Before Income Tax Expense	423.6		381.9			41.7			10.9		1,146.9		1,123.0		23.9			2.1		419.2		392.3		26.9			6.9
Income Tax Expense	156.4		144.1			12.3			8.5		428.2		420.7		7.5			1.8		157.8		146.2		11.6			7.9
Net Income	267.2		237.8			29.4			12.4		718.7		702.3		16.4			2.3		261.4		246.1		15.3			6.2
Net Income Attributable to Noncontrolling Interests	1.9		1.9			—			—		5.6		5.6		—			—		1.9		1.9		—			—
Net Income Attributable to Common Shareholders	$	265.3	$	235.9		$	29.4		12.5	%	$	713.1	$	696.7	$	16.4		2.4	%	$	259.5	$	244.2	$	15.3		6.3	%


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

Operating Revenues

A summary of our Operating Revenues by segment is as follows:


	For the Three Months Ended September 30,									For the Nine Months Ended September 30,											For the Three Months Ended March 31,
(Millions of Dollars)	2016		2015		Increase/(Decrease)			Percent		2016			2015			Increase/(Decrease)			Percent		2017			2016			Increase/ (Decrease)			Percent
Electric Distribution	$	1,623.4	$	1,543.7	$	79.7		5.2	%	$	4,362.6		$	4,686.5		$	(323.9	)	(6.9	)%	$	1,401.1		$	1,436.1		$	(35.0	)	(2.4	)%
Natural Gas Distribution	99.2		106.2		(7.0		)	(6.6	)	622.3			799.6			(177.3		)	(22.2	)	403.6			342.6			61.0			17.8
Electric Transmission	306.8		270.4		36.4			13.5		892.5			787.2			105.3			13.4		316.9			283.3			33.6			11.9
Other and Eliminations	10.3		12.8		(2.5		)	(19.5	)	(14.9		)	(9.7		)	(5.2		)	53.6		(16.5		)	(6.4		)	(10.1		)	(a)
Total Operating Revenues	$	2,039.7	$	1,933.1	$	106.6		5.5	%	$	5,862.5		$	6,263.6		$	(401.1	)	(6.4	)%	$	2,105.1		$	2,055.6		$	49.5		2.4	%


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

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


	For the Three Months Ended September 30,						For the Nine Months Ended September 30,						For the Three Months Ended March 31,
	2016	2015	Increase/(Decrease)		Percent		2016	2015	Decrease		Percent		2017	2016	Increase/ (Decrease)		Percent
Electric
Traditional	8,131	8,136	(5	)	(0.1	)%	21,731	22,309	(578	)	(2.6	)%	6,971	6,994	(23	)	(0.3	)%
Decoupled	7,213	7,070	143		2.0		19,235	19,865	(630	)	(3.2	)	6,201	6,225	(24	)	(0.4	)
Total Electric	15,344	15,206	138		0.9		40,966	42,174	(1,208	)	(2.9	)	13,172	13,219	(47	)	(0.4	)

Firm Natural Gas
Traditional	5,270	5,449	(179	)	(3.3	)	31,570	36,355	(4,785	)	(13.2	)	18,905	17,985	920		5.1
Decoupled and Special Contracts	5,653	5,688	(35	)	(0.6	)	36,537	42,134	(5,597	)	(13.3	)	22,241	21,363	878		4.1
Total Firm Natural Gas	10,923	11,137	(214	)	(1.9	)%	68,107	78,489	(10,382	)	(13.2	)%	41,146	39,348	1,798		4.6	%

~~Three Months Ended:~~

Operating Revenues, which primarily consist of base electric and natural gas distribution revenues and tracked revenues further described below, increased by ~~$106.6~~$49.5 million for the three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015.~~2016.

Base electric and natural gas distribution revenues: Base electric distribution segment revenues, excluding LBR, increased ~~$7.8~~$3.2 million ~~due primarily~~for the three months ended March 31, 2017, as compared to the same period in 2016. Operating Revenues increased $4.3 million for the three months ended March 31, 2017, as compared to the same period in 2016, as a result of higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates at CL&P ($5.4 million) and the absence of an authorized ROE reduction in 2015, as stipulated in the PURA 2014 rate case decision, at CL&P ($1.1 million).LBR recognition.

Base natural gas distribution revenues increased $3.4 million for the three months ended March 31, 2017, as compared to the same period in 2016, driven by higher firm natural gas sales volumes due to colder weather in Connecticut in the first quarter of 2017, as compared to the first quarter of 2016, as well as growth in new customer base.

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

Tracked distribution revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through regulatory commission-approved cost tracking mechanisms and therefore, have no impact on earnings. Costs recovered through cost tracking mechanisms include energy supply procurement costs and other energy-related costs for our electric and natural gas customers, retail transmission charges, energy efficiency program costs, and restructuring and stranded cost recovery revenues. In addition, tracked revenues include certain incentives earned and carrying charges. Tracked ~~electric~~natural gas distribution segment revenues increased as a result of an increase in ~~retail electric transmission charges~~natural gas supply costs ($4546.3 million)~~, an increase in federally mandated congestion charges ($40.5 million),~~ and an increase in energy efficiency program revenues ($~~17.4~~10.1 million)~~, an increase~~. Tracked electric distribution revenues decreased as a result of a decrease in ~~stranded cost recovery charges ($13.6 million) and an increase in net metering for distributed generation revenues ($10.8 million), partially offset by decreases in~~electric energy supply costs ($~~60.4~~53.6 million), driven by decreased average retail ~~rates. In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P’s calculated rate base increased, providing~~rates, partially offset by an increase ~~to distribution revenues that impacted earnings of $8.2 million.~~

~~The third quarter 2016 tracked natural gas distribution segment revenues decreased as a result of decreases~~ in ~~natural gas supply costs~~federally-mandated congestion charges ($~~5.4~~12.6 million) ~~and a decrease in energy efficiency program revenues ($2.5 million)~~.

Electric transmission revenues: The electric transmission segment revenues increased by ~~$36.4~~$33.6 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure.

~~Nine Months Ended:~~

~~Operating Revenues decreased by $401.1 million for the nine months ended September 30, 2016, as compared to the same period in 2015.~~

~~Base electric and natural gas distribution revenues~~: Base electric distribution segment revenues increased by $5.6 million due primarily to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates at CL&P ($16.1 million) and the absence of an authorized ROE reduction in 2015, as stipulated in the PURA 2014 rate case decision, at CL&P ($3.3 million), partially offset by a 2.6 percent decrease in non-decoupled retail electric sales volumes due primarily to increased customer energy conservation efforts and warmer than normal weather in the first quarter of 2016, as compared to the much colder than normal temperatures in the first quarter of 2015 ($13.8 million).

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

Firm natural gas base distribution segment revenues decreased $9.2 million due primarily to a 13.2 percent decrease in traditional firm natural gas sales volumes as a result of warmer than normal weather experienced in the first quarter of 2016, as compared to much colder than normal temperatures in the first quarter of 2015, partially offset by the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016.

~~Tracked distribution revenues:~~ Tracked electric distribution segment revenues decreased as a result of decreases in energy supply costs ($570.3 million), driven by decreased average retail rates and lower sales volumes, partially offset by an increase in retail electric transmission charges ($82.9 million), an increase in federally mandated congestion charges ($70.4 million), an increase in energy efficiency program revenues ($45.2 million), an increase in stranded cost recovery charges ($29.5 million) and an increase in net metering for distributed generation revenues ($25.7 million). In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P’s calculated rate base increased, providing an increase to distribution revenues that impacted earnings of $17.5 million.

The first nine months of 2016 tracked natural gas distribution segment revenues decreased as a result of decreases in natural gas supply costs ($143.2 million) driven by decreased average rates and lower sales volumes, and a decrease in energy efficiency program revenues ($25.5 million).

~~Electric transmission revenues:~~ The electric transmission segment revenues increased by $105.3 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure and the absence in 2016 of a $20 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order.

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

Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity and natural gas on behalf of our customers. These energy supply costs are recovered from customers in rates through cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power, Fuel and Transmission expense decreased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same ~~periods~~period in ~~2015,~~2016, due primarily to the following:


(Millions of Dollars)	Three Months Ended Increase/(Decrease)			Nine Months Ended Increase/(Decrease)			Increase/(Decrease)
Electric Distribution	$	(98.5	)	$	(551.3	)	$	(62.1	)
Natural Gas Distribution	(6.3		)	(142.2		)	41.1
Transmission	68.0			145.6			19.7
Total Purchased Power, Fuel and Transmission	$	(36.8	)	$	(547.9	)	$	(1.3	)

The decrease in purchased power expense at the electric distribution business was driven by lower prices associated with the procurement of energy supply and ~~a decrease in the amount of electricity generated by PSNH facilities for both the three and nine months ended September 30, 2016, as compared to the same periods in 2015, as well as~~ lower sales volumes for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015.~~2016. The ~~decrease~~increase in purchased power expense at the natural gas distribution business was due to ~~lower~~higher sales ~~volumes and lower average natural gas prices.~~volumes. The increase in transmission costs was primarily the result of an increase in costs billed by ISO-NE that support regional grid investment.

Operations and Maintenance expense includes tracked costs and costs that are part of base electric and natural gas distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense ~~decreased~~increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same ~~periods~~period in ~~2015,~~2016, due primarily to the following:


(Millions of Dollars)	Three Months Ended Increase/(Decrease)			Nine Months Ended Increase/(Decrease)			Increase/(Decrease)
Base Electric Distribution:
Absence of 2015 resolution of basic service bad debt adder mechanism at NSTAR Electric	$	—		$	24.2
Storm restoration costs	5.0			11.3			$	8.0
Vegetation management costs	1.1			5.7
Shared corporate costs (including computer software depreciation at Eversource Service)							5.5
System resiliency project costs at CL&P							2.2
Employee-related expenses, including labor and benefits	(8.4		)	(13.7		)	(8.8		)
Absence of 2015 contribution to create clean energy fund in connection with the generation divestiture agreement at PSNH	—			(5.0		)
Bad debt expense							(3.2		)
Other operations and maintenance	3.5			1.1			0.6
Total Base Electric Distribution	1.2			23.6			4.3
Total Base Natural Gas Distribution:
Employee-related expenses, including labor and benefits	(0.1		)	(11.9		)
Shared corporate costs (including computer software depreciation at Eversource Service)							1.3
Other operations and maintenance	2.3			5.3			2.2
Total Base Natural Gas Distribution	2.2			(6.6		)	3.5
Total Tracked costs (Electric Distribution, Electric Transmission and Natural Gas Distribution)	13.9			21.6			9.4
Other and eliminations:
Integration costs	(2.9		)	(13.4		)
Absence of Eversource’s unregulated electrical contracting business due to sale in April 2015, net	(3.3		)	(13.9		)
Eversource Parent and Other Companies	(5.6		)	(10.1		)	(2.0		)
Eliminations	(8.1		)	(12.9		)	(5.0		)
Total Operations and Maintenance	$	(2.6	)	$	(11.7	)	$	10.2

Depreciation expense increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same ~~periods~~period in ~~2015,~~2016, due primarily to higher utility plant in service balances.

Amortization of Regulatory ~~Assets/(Liabilities),~~Assets, Net expense ~~(the costs of which are tracked) include~~includes the deferral of energy supply and energy-related costs included in certain regulatory-approved tracking mechanisms, and the amortization of certain costs. The deferral adjusts expense to match the corresponding revenues. Amortization of Regulatory ~~Assets/(Liabilities),~~Assets, Net, increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same ~~periods~~period in ~~2015,~~2016, due primarily to the deferral of energy supply and energy-related costs which can fluctuate from period to period based on the timing of costs incurred and the related rate changes to recover these costs. Energy supply and energy-related costs at CL&P, NSTAR Electric, PSNH and WMECO, which are the primary drivers in amortization, are recovered from customers in rates and have no impact on earnings. The increase in Amortization of Regulatory Assets/(Liabilities), Net for the nine months ended September 30, 2016 includes the absence in 2016 of the $11.7 million benefit recorded in the first quarter of 2015 at NSTAR Electric in connection with the Comprehensive Settlement Agreement associated with the CPSL program filings.

Energy Efficiency Programs expense ~~(the costs of which are tracked)~~ increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same ~~periods~~period in ~~2015,~~2016, due primarily to the deferral ~~adjustments at NSTAR Electric, partially offset by deferral adjustments~~adjustment for the natural gas businesses, which ~~reflect~~reflects the actual costs of energy efficiency programs compared to the estimated amounts billed to customers, and the timing of the recovery of energy efficiency costs incurred in accordance with the ~~three-year~~ program guidelines established by the ~~DPU.~~regulatory commissions. The deferrals adjust expense to match the energy efficiency programs revenue. The costs for various state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates and have no impact on earnings.

Taxes Other Than Income Taxes expense ~~increased~~decreased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same ~~periods~~period in ~~2015,~~2016, due ~~primarily~~ to lower employment-related taxes and a decrease in property tax rates at NSTAR Electric, partially offset by an increase in property taxes ~~as a result of~~at CL&P due to higher utility plant ~~balances and an increase in gross earnings taxes (the costs of which are tracked).~~balances.

Interest Expense increased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same ~~periods~~period in ~~2015,~~2016, due primarily to higher interest on long-term debt ($~~9.5 million and $25.7 million, respectively)~~4.9 million) as a result of new debt ~~issuances, partially offset by an increase in AFUDC borrowed funds ($1.4 million and $2.9 million, respectively).~~issuances.

Other Income, Net increased for the three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to an increase in earnings related to equity method investments ($4.7 million), higher AFUDC related to equity funds ($~~2.8~~2.5 million)~~, an increase related to officer insurance policies ($1.9 million),~~ and an increase in net gains related to the deferred compensation plans ($~~0.8~~2.1 million).

Income Tax Expense increased for the three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to higher pre-tax earnings ($~~14.3~~9.4 million)~~, higher state income taxes ($3.4 million),~~ and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($~~2.4 million), partially offset by the true up of the return to provision impacts and a higher tax benefit from a reduction in tax reserves ($7.6~~2.2 million).

Income Tax Expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($9 million), higher state income taxes ($5.9 million), and flow-through items and permanent differences ($3.5 million), partially offset by the true up of the return to provision impacts and a higher tax benefit from a reduction in tax reserves ($7.6 million), and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($2.9 million).

RESULTS OF OPERATIONS – THE CONNECTICUT LIGHT AND POWER COMPANY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P for the three ~~and nine~~ months ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~ included in this combined Quarterly Report on Form 10-Q:


	For the Three Months Ended September 30,										For the Nine Months Ended September 30,									For the Three Months Ended March 31,
(Millions of Dollars)	2016		2015			Increase/ (Decrease)			Percent		2016		2015		Increase/ (Decrease)			Percent		2017		2016		Increase/ (Decrease)			Percent
Operating Revenues	$	760.0	$	704.3		$	55.7		7.9	%	$	2,175.1	$	2,175.7	$	(0.6	)	—	%	$	732.3	$	735.3	$	(3.0	)	(0.4	)%
Operating Expenses:
Purchased Power and Transmission	253.5		274.8			(21.3		)	(7.8	)	760.6		861.6		(101.0		)	(11.7	)	244.9		272.6		(27.7		)	(10.2	)
Operations and Maintenance	123.0		122.3			0.7			0.6		356.4		358.3		(1.9		)	(0.5	)	128.2		110.8		17.4			15.7
Depreciation	57.7		54.8			2.9			5.3		172.2		159.9		12.3			7.7		59.8		57.0		2.8			4.9
Amortization of Regulatory Assets/(Liabilities), Net	23.4		(22.9		)	46.3			(a)		30.3		17.9		12.4			69.3
Amortization of Regulatory Assets, Net																				12.8		9.9		2.9			29.3
Energy Efficiency Programs	44.4		42.6			1.8			4.2		118.0		119.4		(1.4		)	(1.2	)	36.6		38.1		(1.5		)	(3.9	)
Taxes Other Than Income Taxes	81.9		71.6			10.3			14.4		227.9		201.7		26.2			13.0		74.0		75.4		(1.4		)	(1.9	)
Total Operating Expenses	583.9		543.2			40.7			7.5		1,665.4		1,718.8		(53.4		)	(3.1	)	556.3		563.8		(7.5		)	(1.3	)
Operating Income	176.1		161.1			15.0			9.3		509.7		456.9		52.8			11.6		176.0		171.5		4.5			2.6
Interest Expense	36.1		36.7			(0.6		)	(1.6	)	108.6		109.5		(0.9		)	(0.8	)	35.0		36.5		(1.5		)	(4.1	)
Other Income, Net	3.7		2.4			1.3			54.2		10.9		8.6		2.3			26.7		2.8		0.9		1.9			(a)
Income Before Income Tax Expense	143.7		126.8			16.9			13.3		412.0		356.0		56.0			15.7		143.8		135.9		7.9			5.8
Income Tax Expense	57.1		46.6			10.5			22.5		155.4		127.8		27.6			21.6		53.6		48.9		4.7			9.6
Net Income	$	86.6	$	80.2		$	6.4		8.0	%	$	256.6	$	228.2	$	28.4		12.4	%	$	90.2	$	87.0	$	3.2		3.7	%

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

Operating Revenues

CL~~&P’s~~&P's retail sales volumes were as follows:

For the Three Months Ended September 30, For the Nine Months Ended September 30,
2016 2015 Increase Percent 2016 2015 Decrease Percent
Retail Sales Volumes in GWh 6,225
6,103
122
2.0 % 16,541
17,123
(582 ) (3.4 )%



	For the Three Months Ended March 31,
	2017	2016	Decrease		Percent
Retail Sales Volumes in GWh	5,330	5,350	(20	)	(0.4	)%

~~Three Months Ended:~~

CL~~&P’s~~&P's Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, ~~increased~~decreased by ~~$55.7~~$3.0 million for the three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015.~~

Base distribution revenues increased by $6.5 million due to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates ($5.4 million) and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, recorded in the third quarter of 2015 ($1.1 million). 2016.

Fluctuations in CL~~&P’s~~&P's sales volumes do not impact the level of base distribution revenue realized or earnings due to the ~~PURA approved~~PURA-approved revenue decoupling mechanism. CL~~&P’s~~&P's revenue decoupling mechanism permits recovery of a base amount of distribution revenues ($1.059 billion annually) and breaks the relationship between sales volumes and revenues recognized. The revenue decoupling mechanism results in the recovery of approved base distribution revenue requirements.

Fluctuations in the overall level of operating revenues are primarily related to tracked revenues. Tracked revenues consist of certain costs that are recovered from customers in rates through PURA-approved cost tracking mechanisms and therefore, have no impact on earnings. Costs recovered through cost tracking mechanisms include energy supply procurement and other energy-related costs, retail transmission charges, energy efficiency program costs and restructuring and stranded cost recovery revenues. In addition, tracked revenues include certain incentives earned and carrying charges. Tracked distribution revenues ~~increased~~decreased primarily as a result of an increase in federally mandated congestion charges ($40.5 million), an increase in competitive transition assessment charges ($9.7 million) and an increase in retail transmission charges ($9.6 million). In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P’s calculated rate base increased, providing an increase to distribution revenues that impacted earnings of $8.2 million. Partially offsetting these increases was a decrease in energy supply costs ($~~27.1~~30.0 million) driven by decreased average retail rates. In addition, there was a $4.0 million decrease in stranded cost recovery revenue. Partially offsetting these decreases was an increase in federally-mandated congestion charges ($12.6 million).

Transmission revenues increased by ~~$13.1~~$18.9 million due primarily to higher revenue requirements associated with ongoing investments in our transmission infrastructure.

~~Nine Months Ended:~~

~~CL&P’s Operating Revenues decreased by $0.6 million for the nine months ended September 30, 2016, as compared to the same period in 2015.~~

Base distribution revenues increased by $19.4 million due to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates ($16.1 million) and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, recorded in the first nine months of 2015 ($3.3 million).

Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs ($187.1 million) driven by decreased average retail rates and lower sales volumes. Partially offsetting this decrease was an increase in retail transmission charges ($27.4 million), an increase in federally mandated congestion charges ($70.4 million) and an increase in competitive transition assessment charges ($24 million). In addition, as a result of a change to the amounts collected in the system benefits charge, CL&P’s calculated rate base increased, providing an increase to distribution revenues that impacted earnings of $17.5 million.

Transmission revenues increased by $49.3 million due primarily to higher revenue requirements associated with ongoing investments in our transmission infrastructure and the absence in 2016 of a $12.5 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order.

Purchased Power and Transmission expense includes costs associated with purchasing electricity on behalf of CL~~&P’s~~&P's customers. These energy supply costs are recovered from customers in PURA-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power and Transmission expense decreased for the three ~~and nine~~ months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same ~~periods~~period in ~~2015,~~2016, due primarily to the following:


(Millions of Dollars)	Three Months Ended Increase/(Decrease)			Nine Months Ended Increase/(Decrease)			Increase/(Decrease)
Purchased Power Costs	$	(37.0	)	$	(149.7	)	$	(38.3	)
Transmission Costs	15.7			48.7			10.6
Total Purchased Power and Transmission	$	(21.3	)	$	(101.0	)	$	(27.7	)

Included in purchased power costs are the costs associated with CL~~&P’s generation services charge (GSC)~~&P's GSC and deferred energy supply costs. The GSC recovers energy-related costs incurred as a result of providing electric generation service supply to all customers who have not migrated to third party suppliers. The decrease in purchased power costs for the three months ended ~~September 30, 2016,~~March 31, 2017, compared to the same period in 2015, was due primarily to the deferral adjustment of energy supply costs, which can fluctuate from period to period based upon the timing of costs incurred and the related rate changes to recover these costs. The decrease in purchased power costs for the nine months ended September 30, 2016, ~~compared to the same period in 2015,~~ was due primarily to a decrease in the ~~prices~~price of standard offer ~~supply, as well as lower sales volumes.~~supply. The increase in transmission costs was primarily the result of an increase in costs billed by ISO-NE that support regional grid investment.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense increased for the three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, driven by a ~~$2.1~~$9.0 million increase in non-tracked costs, which was primarily attributable to higher storm restoration costs, higher system resiliency project costs, and higher shared corporate costs, partially offset by lower employee-related expenses. In addition, there was an $8.4 million increase in tracked costs, which was primarily attributable to higher transmission ~~expenses, partially offset by a $1.4 million decrease in non-tracked costs, which was primarily attributable to lower public liability claims.~~expenses.

Operations and Maintenance expense decreased for the nine months ended September 30, 2016, as compared to the same period in 2015, driven by a $4.2 million decrease in non-tracked costs, which was primarily attributable to lower public liability claims, lower employee-related expenses, reimbursement of legal fees in the second quarter of 2016, and the absence in 2016 of integration costs recorded in the first nine months of 2015, partially offset by higher storm restoration costs. Tracked costs, which have no earnings impact, increased $2.3 million, which was primarily attributable to higher transmission expenses partially offset by lower bad debt expense.

~~Depreciation~~ ~~expense increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to higher utility plant in service balances.~~

~~Amortization of Regulatory Assets/(Liabilities), Net~~ expense (the costs of which are tracked) includes the deferral of energy supply and energy-related costs and the amortization of storm and other costs. Amortization of Regulatory Assets/(Liabilities), Net increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to the deferral adjustment of energy supply and energy-related costs, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The deferral adjusts expense to match the corresponding revenues. 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.

~~Taxes Other Than Income Taxes~~ expense increased for the three and nine months ended September 30, 2016, as compared to the same periods in 2015, due primarily to an increase in property taxes as a result of higher utility plant balances and an increase in gross earnings taxes (the costs of which are tracked).

Income Tax Expense increased for the three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to higher pre-tax earnings ($~~5.9~~2.7 million), higher state ~~income~~ taxes ($~~0.8~~1.1 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($~~4.3 million), partially offset by the true up of the return to provision impacts and a lower tax benefit from a reduction in tax reserves ($0.5~~0.9 million).

Income Tax Expense increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($19.6 million), higher state income taxes ($2.5 million), and flow-through items and permanent differences ($6.9 million), partially offset by the true up of the return to provision impacts and a lower tax benefit from a reduction in tax reserves ($0.5 million), and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.9 million).

EARNINGS SUMMARY

CL~~&P’s~~&P's earnings increased ~~$6.4~~$3.2 million for the three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to an increase in transmission earnings driven by a higher transmission rate base and higher distribution revenues asdue in part to a ~~result of~~ higher rate base and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision. These favorable earnings impacts were partially offset by a higher effective tax rate, higher property and other taxes expense, and higher depreciation expense.

~~CL&P’s earnings increased $28.4 million~~ for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to an increase in transmission earnings driven by a higher transmission rate base as well as the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge, higher distribution revenues as a result of higher rate base and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, and lower operations and maintenance expense.system resiliency program. These favorable earnings impacts were partially offset by higher ~~property~~operations and ~~other taxes~~maintenance expense and a higher effective tax ~~rate and higher depreciation expense.~~rate.

LIQUIDITY

Cash totaled ~~$8.6~~$15.3 million as of ~~September 30, 2016,~~March 31, 2017, compared with ~~$1.1~~$6.6 million as of December 31, ~~2015.~~2016.

CL&P had cash flows provided by operating activities of $171.6 million for the three months ended March 31, 2017, as compared to $221.2 million in the same period of 2016. The decrease in operating cash flows was due primarily to $117.0 million in lower income tax refunds received in 2017, as compared to 2016. Partially offsetting this decrease was the favorable impact of the timing of regulatory recoveries, primarily related to purchased power costs, and the favorable impacts related to the timing of collections and payments of working capital items.

In March 2017, CL&P issued $300 million of 3.20 percent 2017 Series A First and Refunding Mortgage Bonds due to mature in 2027. The proceeds, net of issuance costs, were used to repay short-term borrowings. Also in March 2017, CL&P repaid at maturity the $150 million of 5.375 percent 2007 Series A First and Refunding Mortgage Bonds, using short-term borrowings.

Eversource parent has a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt, with intercompany loans to certain subsidiaries, including CL&P. The weighted-average interest rate on the commercial paper borrowings as of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015~~2016 was ~~0.66~~1.12 percent and ~~0.72~~0.88 percent, respectively. As of ~~September 30, 2016~~March 31, 2017 and December 31, ~~2015,~~2016, there were intercompany loans from Eversource parent to CL&P of ~~$108.5~~$3.4 million and ~~$277.4~~$80.1 million, respectively.

Eversource parent, and certain of its subsidiaries, including CL&P, are parties to a five-year $1.45 billion revolving credit facility. ~~Effective September 26, 2016, the~~The revolving credit ~~facility’s~~facility's termination date ~~was extended for one additional year to~~is September 4, 2021. There were no borrowings outstanding on the revolving credit facility as of ~~September 30, 2016~~March 31, 2017 or December 31, ~~2015.~~

CL&P had cash flows provided by operating activities of $614.4 million for the nine months ended September 30, 2016, as compared to $421.8 million in the same period of 2015. The increase in operating cash flows was due primarily to a $124.7 million favorable impact due to the change in income tax payments made or refunds received during 2016, as compared to 2015, as well as the favorable impact of the timing of regulatory recoveries, primarily related to purchased power costs. Also contributing to the increase in cash flows was an increase in distribution rates due to higher rate base. Partially offsetting these favorable impacts was the timing of collections and payments related to our working capital items, including accounts receivable and accounts payable. 2016.

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. CL~~&P’s~~&P's investments in property, plant and equipment totaled ~~$438.5~~$181.6 million for the ~~nine~~three months ended ~~September 30, 2016.~~March 31, 2017.

RESULTS OF OPERATIONS – NSTAR ELECTRIC COMPANY AND SUBSIDIARY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for NSTAR Electric for the ~~nine~~three months ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~ included in this combined Quarterly Report on Form 10-Q:



	For the Three Months Ended March 31,
(Millions of Dollars)	2017		2016			Increase/ (Decrease)			Percent
Operating Revenues	$	603.8	$	614.2		$	(10.4	)	(1.7	)%
Operating Expenses:
Purchased Power and Transmission	233.1		254.3			(21.2		)	(8.3	)
Operations and Maintenance	88.4		94.7			(6.3		)	(6.7	)
Depreciation	55.2		51.9			3.3			6.4
Amortization of Regulatory Assets, Net	5.0		4.7			0.3			6.4
Energy Efficiency Programs	67.3		66.2			1.1			1.7
Taxes Other Than Income Taxes	27.4		32.6			(5.2		)	(16.0	)
Total Operating Expenses	476.4		504.4			(28.0		)	(5.6	)
Operating Income	127.4		109.8			17.6			16.0
Interest Expense	22.0		20.9			1.1			5.3
Other Income/(Loss), Net	3.3		(0.3		)	3.6			(a)
Income Before Income Tax Expense	108.7		88.6			20.1			22.7
Income Tax Expense	42.5		34.1			8.4			24.6
Net Income	$	66.2	$	54.5		$	11.7		21.5	%

For the Nine Months Ended September 30,
(Millions of Dollars) 2016 2015 Increase/(Decrease) Percent
Operating Revenues $ 1,986.0
$ 2,134.7
$ (148.7 ) (7.0 )%
Operating Expenses:

Purchased Power and Transmission 764.9
984.0
(219.1 ) (22.3 )
Operations and Maintenance 279.9
228.8
51.1
22.3
Depreciation 159.2
146.8
12.4
8.4
Amortization of Regulatory Assets/(Liabilities), Net 18.3
(10.6 ) 28.9
(a)
Energy Efficiency Programs 212.9
164.8
48.1
29.2
Taxes Other Than Income Taxes 101.8
95.8
6.0
6.3
Total Operating Expenses 1,537.0
1,609.6
(72.6 ) (4.5 )
Operating Income 449.0
525.1
(76.1 ) (14.5 )
Interest Expense 62.2
57.2
5.0
8.7
Other Income, Net 7.6
3.6
4.0
(a)
Income Before Income Tax Expense 394.4
471.5
(77.1 ) (16.4 )
Income Tax Expense 154.5
187.4
(32.9 ) (17.6 )
Net Income $ 239.9
$ 284.1
$ (44.2 ) (15.6 )%

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

Operating Revenues

NSTAR ~~Electric’s~~Electric's retail sales volumes were as follows:

For the Nine Months Ended September 30,
2016 2015 Decrease Percent
Retail Sales Volumes in GWh 15,746
16,260
(514 ) (3.2 )%



	For the Three Months Ended March 31,
	2017	2016	Decrease		Percent
Retail Sales Volumes in GWh	4,979	5,018	(39	)	(0.8	)%

NSTAR ~~Electric’s~~Electric's Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased by ~~$148.7~~$10.4 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015.~~2016.

Base distribution revenues: Base distribution revenues, excluding LBR, ~~decreased $15.9 million in~~remained relatively unchanged for the ~~first nine~~three months of 2016, driven by a 3.2 percent decrease in sales volumes due primarily to increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, and the impact of the warmer than normal weather in the first quarter of 2016,ended March 31, 2017, as compared to ~~much colder than normal temperatures~~the same period in 2016. Operating Revenues increased $4.3 million for the ~~first quarter of 2015. NSTAR Electric is allowed~~three months ended March 31, 2017, as compared to ~~recover LBR related to reductions~~the same period in ~~sales volumes~~2016, as a result of ~~successful energy efficiency programs.~~

Also contributing to the decrease in operating revenues in the first nine months of 2016 was the absence of an $11 million benefit recorded in the first quarter of 2015 related to the Comprehensive Settlement Agreement associated with the recovery ofhigher LBR ~~related to 2009 through 2011 energy efficiency programs.~~ recognition.

Tracked revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through DPU-approved cost tracking mechanisms and therefore, have no impact on earnings. Costs recovered through cost tracking mechanisms include energy supply costs, retail transmission charges, energy efficiency program costs, net metering for distributed generation and transition cost recovery revenues. In addition, tracked revenues include certain incentives earned and carrying charges. Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs ($~~295.8~~22.4 million) driven by decreased average retail rates and lower sales ~~volumes. Partially offsetting this~~volumes, and a decrease ~~was an increase~~ in retail transmission charges ($~~55.1~~7.3 million)~~, an increase in cost recovery related to energy efficiency programs ($47.8 million) and~~. Partially offsetting these decreases were an increase in net metering revenues ($237.3 million), an increase in revenues related to renewable energy requirements ($7.3 million), and an increase in energy efficiency program revenues ($4.0 million).

Transmission revenues increased by ~~$25.2~~$3.6 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission ~~infrastructure and the absence in 2016 of a $2.4 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order.~~

infrastructure.

Purchased Power and Transmission expense includes costs associated with purchasing electricity on behalf of NSTAR ~~Electric’s~~Electric's customers. These energy supply costs are recovered from customers in DPU-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power and Transmission expense decreased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to the following:


(Millions of Dollars)	Increase/(Decrease)			Decrease
Purchased Power Costs	$	(297.3	)	$	(17.5	)
Transmission Costs	78.2			(3.7		)
Total Purchased Power and Transmission	$	(219.1	)	$	(21.2	)

Included in purchased power costs are the costs associated with NSTAR ~~Electric’s~~Electric's basic service charge and deferred energy supply costs. The basic service charge recovers energy-related costs incurred as a result of providing electric generation service supply to all customers who have not migrated to third party suppliers. The decrease in purchased power costs was due primarily to lower prices associated with the procurement of energy supply and lower sales volumes. The ~~increase~~decrease in transmission costs was primarily the result of ~~an increase~~a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense ~~increased~~decreased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, driven by a ~~$33.6~~$6.6 million ~~increase~~decrease in non-tracked costs, which was primarily attributable to ~~the absence in 2016 of the resolution of the basic service~~lower employee-related expenses and lower bad debt ~~adder mechanism recorded in the first quarter of 2015 ($24.2 million),~~expense, partially offset by higher ~~vegetation management expense and higher storm restoration~~shared corporate costs. ~~Additionally, there was a $17.5 million increase in tracked~~Tracked costs ~~which have no earnings impact, that was primarily attributable to higher employee-related expenses due to~~ increased ~~current year collections of a prior year pension and PBOP costs underrecovery and higher bad debt expense.~~$0.3 million.

Depreciation expense increased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to higher utility plant in service balances.

~~Amortization of Regulatory Assets/(Liabilities), Net~~Taxes Other Than Income Taxes reflects the absence in 2016 of an $11.7 million benefit recognized in the first quarter of 2015 relating to the Comprehensive Settlement Agreement, and the deferral adjustment of certain costs that exceeded billed revenuesexpense decreased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015. The deferral adjusts expense~~2016, due primarily to match the corresponding revenues. These deferred costs, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs, are recovered from customersa decrease in property tax rates and ~~have no impact on earnings.~~lower employment-related taxes.

~~Energy Efficiency Programs~~Other Income/(Loss), Net ~~expense (the costs of which are tracked)~~ increased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in 2015, due primarily to the deferral adjustment, which reflects the actual costs billed to energy efficiency programs compared to the amount billed to customers and the timing of the recovery of energy efficiency costs incurred in accordance with the three-year program guidelines established by the DPU. The deferral adjusts expense to match the energy efficiency programs revenue.

~~Taxes Other Than Income Taxes~~ ~~expense increased for the nine months ended September 30,~~ 2016, ~~as compared to the same period in 2015, due primarily to an increase in property taxes as a result of higher utility plant balances.~~

~~Other Income, Net~~ ~~increased for the nine months ended September 30, 2016, as compared to the same period in 2015,~~ due primarily to higher AFUDC on equity funds ($~~4.1~~1.2 million).

~~Interest Expense~~ ~~increased for the nine months ended September 30, 2016, as compared~~, an increase related to ~~the same period in 2015, due primarily to higher interest on long-term debt~~officer insurance policies ($~~8.2~~1.2 million) ~~as a result of new debt issuances, partially offset by~~and an increase in ~~AFUDC borrowed funds~~gains related to deferred compensation plans ($21.1 million).

Income Tax Expense ~~decreased~~increased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to ~~lower~~higher pre-tax earnings ($~~27.4~~7.0 million), ~~lower~~higher state ~~income~~ taxes ($~~4.6~~0.8 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) ~~($1.5 million),~~ and ~~the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions~~permanent differences ($~~1 million), partially offset by other items ($1.6~~0.6 million).

EARNINGS SUMMARY

NSTAR ~~Electric’s~~Electric's earnings ~~decreased $44.2~~increased $11.7 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to the absence in 2016 of both the 2015 resolution of the basic service bad debt adder mechanism ($14.5 million) and the 2015 favorable impact associated with the Comprehensive Settlement Agreement ($13 million), lower ~~retail sales volumes, higher depreciation expense, and higher~~ operations and maintenance ~~expense.~~expense, higher distribution revenues as a result of higher lost base revenues, higher earnings from net metering and higher energy efficiency incentives, lower property and other tax expense, and an increase in transmission earnings driven by a higher transmission rate base. These ~~unfavorable~~favorable earnings impacts were partially offset by ~~an increase in transmission earnings, which was driven by a~~ higher ~~transmission rate base as well as the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge.~~

depreciation expense and higher interest expense.

LIQUIDITY

NSTAR Electric had cash flows provided by operating activities of ~~$564.3~~$133.7 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to ~~$502.3~~$96.3 million in the same period of ~~2015.~~2016. The increase in operating cash flows was due primarily to a favorable impact related to an increase in regulatory recoveries due to collections from customers in excess of purchased power costs ~~costs~~ and ~~energy efficiency programs. In addition,~~changes in the timing of ~~accounts payable payments had a favorable impact on operating cash flows.~~working capital items. Partially offsetting these favorable impacts was ~~a $43.3~~$4.9 million ~~reduction~~ in lower income tax refunds received in ~~2016,~~2017, as compared to 2016.

NSTAR Electric has a $450 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. As of March 31, 2017 and December 31, 2016, NSTAR Electric had $174.5 million and $126.5 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $275.5 million and $323.5 million of available borrowing capacity as of March 31, 2017 and December 31, 2016, respectively. The weighted-average interest rate on these borrowings as of March 31, 2017 and December 31, 2016 was 0.86 percent and 0.71 percent, respectively. NSTAR Electric is a party to a five-year $450 million revolving credit facility. The revolving credit facility's termination date is September 4, 2021. The revolving credit facility serves to backstop NSTAR Electric's $450 million commercial paper program. There were no borrowings outstanding on the ~~same period in 2015 and an increase in Pension Plan contributions~~revolving credit facility as of ~~$15.8 million in 2016, as compared to 2015 and changes related to working capital items.~~March 31, 2017 or December 31, 2016.

RESULTS OF OPERATIONS – PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for PSNH for the ~~nine~~three months ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~ included in this combined Quarterly Report on Form 10-Q:


	For the Nine Months Ended September 30,									For the Three Months Ended March 31,
(Millions of Dollars)	2016		2015		Increase/(Decrease)			Percent		2017		2016		Increase/ (Decrease)			Percent
Operating Revenues	$	727.8	$	761.1	$	(33.3	)	(4.4	)%	$	253.2	$	242.3	$	10.9		4.5	%
Operating Expenses:
Purchased Power, Fuel and Transmission	155.7		200.5		(44.8		)	(22.3	)	61.8		50.2		11.6			23.1
Operations and Maintenance	187.2		200.1		(12.9		)	(6.4	)	62.4		59.2		3.2			5.4
Depreciation	86.5		78.0		8.5			10.9		30.7		28.3		2.4			8.5
Amortization of Regulatory Assets, Net	14.5		29.2		(14.7		)	(50.3	)	5.4		8.5		(3.1		)	(36.5	)
Energy Efficiency Programs	10.9		11.0		(0.1		)	(0.9	)	3.7		3.6		0.1			2.8
Taxes Other Than Income Taxes	64.5		61.4		3.1			5.0		20.9		21.8		(0.9		)	(4.1	)
Total Operating Expenses	519.3		580.2		(60.9		)	(10.5	)	184.9		171.6		13.3			7.8
Operating Income	208.5		180.9		27.6			15.3		68.3		70.7		(2.4		)	(3.4	)
Interest Expense	37.4		34.6		2.8			8.1		12.8		12.5		0.3			2.4
Other Income, Net	1.0		2.3		(1.3		)	(56.5	)	1.1		0.2		0.9			(a)
Income Before Income Tax Expense	172.1		148.6		23.5			15.8		56.6		58.4		(1.8		)	(3.1	)
Income Tax Expense	66.3		56.1		10.2			18.2		22.3		22.3		—			—
Net Income	$	105.8	$	92.5	$	13.3		14.4	%	$	34.3	$	36.1	$	(1.8	)	(5.0	)%

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

Operating Revenues

~~PSNH’s~~PSNH's retail sales volumes were as follows:

For the Nine Months Ended September 30,
2016 2015 Decrease Percent
Retail Sales Volumes in GWh 5,985
6,049
(64 ) (1.1 )%



	For the Three Months Ended March 31,
	2017	2016	Increase	Percent
Retail Sales Volumes in GWh	1,992	1,976	16	0.8	%

~~PSNH’s~~PSNH's Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, ~~decreased~~increased by ~~$33.3~~$10.9 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015.~~2016.

Base distribution revenues: Base distribution revenues increased ~~$2.1~~$2.9 million due primarily to a ~~$4.4~~$1.0 million increase as a result of a distribution rate ~~increases~~increase effective July 1, ~~2015 and July 1,~~ 2016. Partially offsetting this increase was a 1.1 percent decrease in sales volumes due primarily to increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, and the impact of the warmer than normal weather in the first quarter of 2016, as compared to much colder than normal temperatures in the first quarter of 2015.

Tracked revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through NHPUC-approved cost tracking mechanisms and therefore, have no impact on earnings. Costs recovered through cost tracking mechanisms include energy supply costs and costs associated with the generation of electricity for customers, retail transmission charges, energy efficiency program costs and stranded cost recovery revenues. In addition, tracked revenues include certain incentives earned and carrying charges. Tracked distribution revenues ~~decreased~~increased primarily as a result of ~~a decrease~~an increase in retail transmission charges ($5.8 million) and an increase in both energy supply costs and ~~a reduction in~~ wholesale generation revenues (totaling $3.7 million) for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period of ~~2015 ($39.6 million),~~2016. The increase in energy supply costs was driven by ~~lower sales volumes. In addition, stranded cost recovery and~~increased average retail ~~transmission charges decreased by $6.4 million and $3 million, respectively, for the nine months ended September 30, 2016, as compared~~rates. Partially offsetting these increases was a decrease in revenues related to the ~~same period in 2015.~~timing of the sale of RECs ($7.7 million).

Transmission revenues increased by ~~$17.2~~$6.2 million due primarily to higher revenue requirements associated with ongoing investments in our transmission ~~infrastructure and the absence in 2016 of a $1 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order.~~infrastructure.

Purchased Power, Fuel and Transmission expense includes costs associated with ~~PSNH’s~~PSNH's generation of electricity, as well as purchasing electricity on behalf of its customers. These generation and energy supply costs are recovered from customers in NHPUC-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power, Fuel and Transmission expense ~~decreased~~increased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to the following:


(Millions of Dollars)	Increase/(Decrease)			Increase
Purchased Power and Generation Fuel Costs	$	(56.9	)	$	2.0
Transmission Costs	12.1			9.6
Total Purchased Power, Fuel and Transmission	$	(44.8	)	$	11.6

In order to meet the demand of customers who have not migrated to third party suppliers, PSNH procures power through power supply contracts and spot purchases in the competitive New England wholesale power market and/or produces power through its own generation. The ~~decrease~~increase in purchased power and generation fuel costs was due primarily to ~~a decrease in the amount of electricity generated by PSNH facilities.~~Regional Greenhouse Gas Initiative related expenses. The increase in transmission costs was primarily the result of an increase in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed ~~by ISO-NE that support regional grid investment.~~to customers.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense ~~decreased~~increased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, driven by a ~~$9.9~~$3.4 million increase in tracked costs, which was primarily attributable to higher transmission expenses, partially offset by a $0.2 million decrease in non-tracked costs that was primarily attributable to the absence in 2016 of a $5 million contribution recorded in the second quarter of 2015 to create a clean energy fund in connection with the generation divestiture agreement, and lower employee-related expenses. Additionally, there was a $3 million decrease in tracked costs that was primarily attributable to lower contractor costs due to the timing of planned outages at PSNH’s generation facilities partially offset by higher transmission expenses, which have no earnings impact.costs.

Amortization of Regulatory Assets, Net expense ~~(the costs of which are tracked)~~ includes the deferral to expense of energy supply costs and the amortization of certain costs, which are recovered from customers in rates and have no impact on earnings. The decrease for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, was due primarily to ~~a decrease in~~ the ~~default energy service~~deferral adjustment of the stranded cost recovery charge. The deferral adjusts expense to match the corresponding revenues.

~~Taxes Other Than Income Taxes~~ ~~expense increased~~

EARNINGS SUMMARY

PSNH's earnings decreased $1.8 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to ~~an increase in property taxes as a result of~~lower generation earnings and higher ~~utility plant balances.~~

~~Income Tax Expense~~ ~~increased for the nine months ended September 30, 2016, as compared to the same period in 2015,~~depreciation expense, partially offset by higher distribution revenues due primarily to ~~higher pre-tax earnings ($8.2 million), higher state taxes ($1.2 million),~~a distribution rate increase effective July 1, 2016 and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($1.2 million), partially offset by other items ($0.3 million) and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.4 million).

~~EARNINGS SUMMARY~~

~~PSNH’s earnings increased $13.3 million for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to~~ an increase in transmission earnings ~~which was~~ driven by a higher transmission rate base as well as the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge, higher generation earnings, lower operations and maintenance expense, and the impact of the distribution rate increases effective July 1, 2015 and July 1, 2016. These favorable earnings impacts were partially offset by higher depreciation expense and lower retail sales volumes.base.

LIQUIDITY

PSNH had cash flows provided by operating activities of ~~$306~~$113.2 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to ~~$243.9~~$156.3 million in the same period of ~~2015.~~2016. The ~~increase~~decrease in operating cash flows was due primarily to ~~the favorable impact~~income tax payments of ~~the timing of payments related~~$9.0 million made in 2017, compared to ~~our accounts payable. In addition,~~ income tax refunds of ~~$41.3~~$53.9 million ~~were~~ received in ~~2016, compared to income tax payments of $5 million~~ the same period in ~~2015. Partially offsetting these favorable impacts were an increase in Pension Plan contributions of $15.8~~2016. In addition, there was a $10.3 million ~~in 2016 and~~decrease related to the use of fuel inventories. Partially offsetting these decreases were $9.7 million lower Pension Plan contributions made in 2017, as compared to 2016 and the favorable impacts related to the timing of collections of accounts receivable and regulatory recoveries.

RESULTS OF OPERATIONS – WESTERN MASSACHUSETTS ELECTRIC COMPANY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for WMECO for the ~~nine~~three months ended ~~September 30,~~March 31, 2017 and 2016 ~~and 2015~~ included in this combined Quarterly Report on Form 10-Q:


	For the Nine Months Ended September 30,									For the Three Months Ended March 31,
(Millions of Dollars)	2016		2015		Increase/(Decrease)			Percent		2017			2016			Increase/ (Decrease)			Percent
Operating Revenues	$	368.5	$	403.2	$	(34.7	)	(8.6	)%	$	130.1		$	128.1		$	2.0		1.6	%
Operating Expenses:
Purchased Power and Transmission	104.4		149.2		(44.8		)	(30.0	)	40.9			39.5			1.4			3.5
Operations and Maintenance	68.0		61.7		6.3			10.2		22.5			21.8			0.7			3.2
Depreciation	34.4		32.4		2.0			6.2		12.0			11.4			0.6			5.3
Amortization of Regulatory Assets, Net	3.3		11.2		(7.9		)	(70.5	)
Amortization of Regulatory (Liabilities)/Assets, Net										(0.5		)	1.2			(1.7		)	(a)
Energy Efficiency Programs	33.6		32.7		0.9			2.8		10.7			10.9			(0.2		)	(1.8	)
Taxes Other Than Income Taxes	30.4		28.4		2.0			7.0		10.3			10.2			0.1			1.0
Total Operating Expenses	274.1		315.6		(41.5		)	(13.1	)	95.9			95.0			0.9			0.9
Operating Income	94.4		87.6		6.8			7.8		34.2			33.1			1.1			3.3
Interest Expense	18.3		19.0		(0.7		)	(3.7	)	6.2			6.0			0.2			3.3
Other Income, Net	0.1		2.4		(2.3		)	(95.8	)
Other Income/(Loss), Net										—			(0.2		)	0.2			(100.0	)
Income Before Income Tax Expense	76.2		71.0		5.2			7.3		28.0			26.9			1.1			4.1
Income Tax Expense	30.1		28.6		1.5			5.2		10.8			10.1			0.7			6.9
Net Income	$	46.1	$	42.4	$	3.7		8.7	%	$	17.2		$	16.8		$	0.4		2.4	%

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

Operating Revenues

~~WMECO’s~~WMECO's retail sales volumes were as follows:

For the Nine Months Ended September 30,
2016 2015 Decrease Percent
Retail Sales Volumes in GWh 2,695
2,742
(47 ) (1.7 )%



	For the Three Months Ended March 31,
	2017	2016	Decrease		Percent
Retail Sales Volumes in GWh	870	876	(6	)	(0.6	)%

~~WMECO’s~~WMECO's Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, ~~decreased~~increased by ~~$34.7~~$2.0 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015.~~2016.

Fluctuations in ~~WMECO’s~~WMECO's sales volumes do not impact the level of base distribution revenue realized or earnings due to the ~~DPU approved~~DPU-approved revenue decoupling mechanism. ~~WMECO’s~~WMECO's revenue decoupling mechanism permits recovery of a base amount of distribution revenues ($132.4 million annually) and breaks the relationship between sales volumes and revenues recognized. The revenue decoupling mechanism results in the recovery of approved base distribution revenue requirements.

Transmission revenues increased by ~~$13.6~~$4.9 million due primarily to ~~the absence in 2016 of a $4.1 million reserve charge recorded in the first quarter of 2015 associated with the March 2015 FERC ROE order and~~ higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Purchased Power and Transmission expense includes costs associated with the purchasing of energy supply on behalf of ~~WMECO’s~~WMECO's customers. These energy supply costs are recovered from customers in DPU-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power and Transmission expense ~~decreased~~increased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, due primarily to the following:


(Millions of Dollars)	Increase/(Decrease)			Increase/(Decrease)
Purchased Power Costs	$	(51.3	)	$	(1.9	)
Transmission Costs	6.5			3.3
Total Purchased Power and Transmission	$	(44.8	)	$	1.4

Included in purchased power costs are the costs associated with ~~WMECO’s~~WMECO's basic service charge and deferred energy supply costs. The basic service charge recovers energy-related costs incurred as a result of providing electric generation service supply to all customers who have not migrated to third party suppliers. The decrease in purchased power costs was due primarily to lower prices associated with the procurement of energy ~~supply and lower sales volumes.~~supply. The increase in transmission costs was primarily the result of an increase in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed ~~by ISO-NE that support regional grid investment.~~to customers.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense increased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015,~~2016, driven by a ~~$3.7~~$2.1 million increase in ~~tracked~~non-tracked costs, which ~~have no earnings impact, that~~ was primarily attributable to higher ~~transmission expenses~~storm restoration costs, higher shared corporate costs, and higher bad expense. Tracked costs decreased $1.4 million, which was primarily attributable to the deferral ofadjustment for RECs generated and sold by the WMECO solar program, ~~and an increase of $2.6 million in non-tracked costs that was primarily attributable to~~partially offset by higher ~~employee-related expenses and higher public liability claims.~~transmission expenses.

~~Depreciation~~Amortization of Regulatory (Liabilities)/Assets, Net expense ~~increased~~decreased for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015, due primarily to higher utility plant in service balances.~~

~~Amortization of Regulatory Assets, Net~~ ~~expense (the costs of which are tracked) decreased for the nine months ended September 30,~~ 2016, ~~as compared to the same period in 2015,~~ due to the timing of refunds or recovery of tracked costs to/from customers in rates. These costs have no impact on earnings.

~~Taxes Other Than Income Taxes~~ ~~expense~~

EARNINGS SUMMARY

WMECO's earnings increased $0.4 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to the same period in ~~2015, due primarily to an increase in property taxes as a result of higher utility plant balances.~~

~~Other Income, Net~~ ~~decreased for the nine months ended September 30,~~ 2016, ~~as compared to the same period in 2015, due primarily to lower AFUDC on equity funds ($1.4 million) and a decrease in net gains related to the deferred compensation plans ($0.3 million).~~

~~Income Tax Expense~~ increased for the nine months ended September 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($1.9 million), partially offset by other items ($0.2 million) and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.2 million).

~~EARNINGS SUMMARY~~

~~WMECO’s earnings increased $3.7 million for the nine months ended September 30, 2016, as compared to the same period in 2015,~~ due primarily to an increase in transmission earnings ~~which was~~ driven by ~~the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge as well as~~ a higher transmission rate base, ~~and lower interest expense on long-term debt. These favorable earnings impacts were~~ partially offset by higher operations and maintenance ~~expense, higher property and other taxes expense, and higher depreciation~~ expense.

LIQUIDITY

WMECO had cash flows provided by operating activities of ~~$124.8~~$22.6 million for the ~~nine~~three months ended ~~September 30, 2016,~~March 31, 2017, as compared to ~~$68~~$50.7 million in the same period of ~~2015.~~2016. The ~~increase~~decrease in operating cash flows was due primarily to a decrease of $22.4 million in income tax refunds in 2017, as compared to 2016 and the timing of collections of accounts ~~receivable and an increase of $21 million in income tax refunds in 2016, as compared to the same period in 2015.~~receivable.


ITEM 3.	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~~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

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.

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 ~~September 30, 2016,~~March 31, 2017, our Regulated companies did not hold collateral (letters of credit) from counterparties related to our standard service contracts. As of ~~September 30, 2016,~~March 31, 2017, Eversource had ~~$16.7~~$24.3 million of cash posted with ISO-NE related to energy ~~purchase~~ transactions.

We have provided additional disclosures regarding interest rate risk management and credit risk management in Part II, Item 7A, ~~“Quantitative~~"Quantitative and Qualitative Disclosures about Market Risk,”" in ~~Eversource’s 2015~~Eversource's 2016 Form 10-K, which is incorporated herein by reference. There have been no additional risks identified and no material changes with regard to the items previously disclosed in the Eversource ~~2015~~2016 Form 10-K.


ITEM 4.	CONTROLS AND PROCEDURES

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 ~~September 30, 2016~~March 31, 2017 to determine whether they are effective in ensuring that the disclosure of required information is made timely and in accordance with the Securities Exchange Act of 1934 and the rules and regulations of the SEC. This evaluation was made under ~~management’s~~management's supervision and with ~~management’s~~management's participation, including the principal executive officer and principal financial officer as of the end of the period covered by this Quarterly Report on Form 10-Q. 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.

During the third quarter of 2016, we implemented a new time keeping and human resource system resulting in a material change in internal controls over financial reporting. These new systems standardized the timekeeping and human resource management for Eversource and provides for common time and employee data collection and reporting processes, practices and structures. Pre-implementation testing and post-implementation reviews were conducted by management to ensure that internal controls surrounding the system implementation process, the applications, and the closing process were properly designed to prevent material financial statement errors. Such procedures included the review of required documents, user acceptance testing, change management procedures, access controls, data migration strategies and reconciliations, application interface testing and other standard application controls.

There have been no changes ~~except previously discussed,~~ in internal controls over financial reporting for Eversource, CL&P, NSTAR Electric, PSNH and WMECO during the quarter ended ~~September 30, 2016~~March 31, 2017 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.

PART II. OTHER INFORMATION


ITEM 1.	LEGAL PROCEEDINGS

We are parties to various legal proceedings. We have disclosed these legal proceedings in Part I, Item 3, ~~“Legal~~"Legal Proceedings,”" and elsewhere in our ~~2015~~2016 Form 10-K. These disclosures are incorporated herein by reference.

~~In August 2013, the Yankee Companies each filed lawsuits against the DOE seeking recovery of actual damages incurred in the years 2009 through 2012, as described under the caption “Yankee Companies v. U.S. Department of Energy” “DOE Phase III Damages~~” in Part I, Item 3, “Legal Proceedings” of our 2015 Form 10-K. On March 25, 2016, the court issued its decision and awarded the Yankee Companies approximately $76.8 million of the $77.9 million in damages sought in Phase III. The decision became final on July 18, 2016, and the Yankee Companies received the awards from the DOE on October 14, 2016. The Yankee Companies have filed a request with FERC seeking approval of the proposed distribution of certain amounts of the awarded damages proceeds to member companies, including CL&P, NSTAR Electric, PSNH, and WMECO. Subject to receipt of FERC approval, CYAPC and MYAPC expect to be able to make distributions in December 2016. MYAPC also anticipates refunding approximately $57 million from its spent nuclear fuel trust, a portion of which will be refunded to the Eversource utility subsidiaries. In total, Eversource expects to receive approximately $26 million, of which CL&P expects to receive $13.6 million, NSTAR Electric expects to receive $5 million, PSNH expects to receive $3.9 million, and WMECO expects to receive $3.6 million. These anticipated amounts will be refunded to the customers of the respective Eversource utility subsidiaries.

~~Other than as set forth above, there~~There have been no additional material legal proceedings identified and no further material changes with regard to the legal proceedings previously disclosed in our ~~2015~~2016 Form ~~10-K and our Form 10-Q filed for the quarter ended June 30, 2016.~~10-K.


ITEM 1A.	RISK FACTORS

We are subject to a variety of significant risks in addition to the matters set forth under ~~“Forward-Looking~~"Forward-Looking Statements,”" in Item 2, ~~“Management’s~~"Management's Discussion and Analysis of Financial Condition and Results of Operations,”" of this Quarterly Report on Form 10-Q. We have identified a number of these risk factors in Part I, Item 1A, ~~“Risk~~"Risk Factors,”" in our ~~2015~~2016 Form 10-K, which risk factors are incorporated herein by reference. These risk factors should be considered carefully in evaluating our risk profile. There have been no additional risk factors identified and no material changes with regard to the risk factors previously disclosed in our ~~2015~~2016 Form 10-K.


ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

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~~Company's Incentive Plan and Dividend Reinvestment Plan and matching contributions under the Eversource 401k Plan.

Period
Total Number of
Shares Purchased
Average Price
Paid per Share
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans and Programs (at month end)
July 1 – July 31, 2016 103,301
$ 59.31
—
—
August 1 – August 31, 2016 5,468
56.26
—
—
September 1 – September 30, 2016 13,172
54.33
—
—
Total 121,941
$ 58.63
—
—



Period	Total Number of Shares Purchased	Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans and Programs (at month end)
January 1 – January 31, 2017	6,374	$	54.71	—	—
February 1 – February 28, 2017	291,389	56.95		—	—
March 1 – March 31, 2017	109,367	59.24		—	—
Total	407,130	$	57.53	—	—


ITEM 6.	EXHIBITS

Each document described below is filed herewith, unless designated with an asterisk (*), which exhibits are incorporated by reference by the registrant under whose name the exhibit appears.



	Exhibit No.	Description

	Listing of Exhibits (Eversource)

	3.1	Declaration of Trust of Eversource Energy, as amended through May 3, 2017

*	4.1	Eighth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of March 10, 2017, relating to $300 million of Senior Notes, Series K, Due 2022 (incorporated by reference to Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed March 16, 2017, File No. 001-05324)

	12	Ratio of Earnings to Fixed Charges

	31	Certification by the Chief Executive Officer of Eversource Energy pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	31.1	Certification by the Chief Financial Officer of Eversource Energy pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	32	Certification by the Chief Executive Officer and Chief Financial Officer of Eversource Energy pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

	Listing of Exhibits (CL&P)

*	4.1	Supplemental Indenture (2017 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee dated as of March 10, 2017 (incorporated by reference to Exhibit 4.1, CL&P Current Report on Form 8-K filed March 16, 2017, File No. 000-00404)

	12	Ratio of Earnings to Fixed Charges

	31	Certification by the Chairman of The Connecticut Light and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	31.1	Certification by the Chief Financial Officer of The Connecticut Light and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	32	Certification by the Chairman and the Chief Financial Officer of The Connecticut Light and Power Company pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

	Listing of Exhibits (NSTAR Electric Company)

	12	Ratio of Earnings to Fixed Charges

	31	Certification by the Chairman of NSTAR Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	31.1	Certification by the Chief Financial Officer of NSTAR Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	32	Certification by the Chairman and the Chief Financial Officer of NSTAR Electric Company pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

	Listing of Exhibits (PSNH)

	12	Ratio of Earnings to Fixed Charges

	31	Certification by the Chairman of Public Service Company of New Hampshire pursuant to Section 302 of the Sarbanes-Oxley Act of 2002



	31.1		Certification by the Chief Financial Officer of Public Service Company of New Hampshire pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	32		Certification by the Chairman and the Chief Financial Officer of Public Service Company of New Hampshire pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002



Listing of Exhibits (WMECO)

	12	Ratio of Earnings to Fixed Charges

	31	Certification by the Chairman of Western Massachusetts Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	31.1	Certification by the Chief Financial Officer of Western Massachusetts Electric Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

	32	Certification by the Chairman and the Chief Financial Officer of Western Massachusetts Electric Company pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

	Listing of Exhibits (Eversource, CL&P, NSTAR Electric, PSNH, WMECO)

	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

SIGNATURE

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

~~November 4, 2016~~May 5, 2017	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE



	THE CONNECTICUT LIGHT AND POWER COMPANY

~~November 4, 2016~~May 5, 2017	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE



	NSTAR ELECTRIC COMPANY

~~November 4, 2016~~May 5, 2017	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE



	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE

~~November 4, 2016~~May 5, 2017	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE



	WESTERN MASSACHUSETTS ELECTRIC COMPANY

~~November 4, 2016~~May 5, 2017	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

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