10-Q

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 June 30, 2016
	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:  (860) 286-5000	04-2147929

0-00404 THE CONNECTICUT LIGHT AND POWER COMPANY
(a Connecticut corporation)
107 Selden Street
Berlin, Connecticut 06037-1616
Telephone:  (860) 286-5000 06-0303850

1-02301 NSTAR ELECTRIC COMPANY
(a Massachusetts corporation)
800 Boylston Street
Boston, Massachusetts 02199
Telephone:  (860) 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:  (860) 286-5000 02-0181050

0-7624 WESTERN MASSACHUSETTS ELECTRIC COMPANY
(a Massachusetts corporation)
300 Cadwell Drive
Springfield, Massachusetts 01104
Telephone:  (860) 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.  See definition of "accelerated filer" and "large accelerated filer" in Rule 12b-2 of the Exchange Act.  (Check one):

	Large Accelerated Filer	Accelerated Filer	Non-accelerated Filer
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 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' classes of common stock, as of the latest practicable date:

Company - Class of Stock	Outstanding as of July 31, 2016
Eversource Energy Common shares, $5.00 par value	317,207,036 shares
The Connecticut Light and Power Company Common stock, $10.00 par value	6,035,205 shares
NSTAR Electric Company Common stock, $1.00 par value	100 shares
Public Service Company of New Hampshire Common stock, $1.00 par value	301 shares
Western Massachusetts Electric Company Common 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:
ADIT	Accumulated Deferred Income Taxes
AFUDC	Allowance For Funds Used During Construction
AOCI	Accumulated Other Comprehensive Income/(Loss)
ARO	Asset Retirement Obligation
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 technology," to reduce mercury emissions of the Merrimack coal-fired generation station in Bow, New Hampshire
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
Eversource 2015 Form 10-K	The Eversource Energy and Subsidiaries 2015 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

i

HQ	Hydro-Québec, a corporation wholly owned by the Québec government, including its divisions that produce, transmit and distribute electricity in Québec, Canada
HVDC	High voltage direct current
Hydro Renewable Energy	Hydro Renewable Energy, Inc., a wholly owned subsidiary of Hydro-Québec
IPP	Independent Power Producers
ISO-NE Tariff	ISO-NE FERC Transmission, Markets and Services Tariff
kV	Kilovolt
kVa	Kilovolt-ampere
kW	Kilowatt (equal to one thousand watts)
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 Investors Services, Inc.
MW	Megawatt
MWh	Megawatt-Hours
NEEWS	New England East-West Solution
Northern Pass	The high voltage direct current transmission line project from Canada into New Hampshire
NOx	Nitrogen oxides
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 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

ii

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	32
	The Connecticut Light and Power Company	46
	NSTAR Electric Company and Subsidiary	49
	Public Service Company of New Hampshire and Subsidiary	51
	Western Massachusetts Electric Company	53
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	55
ITEM 4.	Controls and Procedures	55
PART II – OTHER INFORMATION
ITEM 1.	Legal Proceedings	56
ITEM 1A.	Risk Factors	56
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	56
ITEM 6.	Exhibits	57
SIGNATURES		59

iii

EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
			June 30,		December 31,
(Thousands of Dollars)			2016		2015
ASSETS
Current Assets:
	Cash and Cash Equivalents		$	38,726	$	23,947
	Receivables, Net			806,340		775,480
	Unbilled Revenues			203,824		202,647
	Taxes Receivable			103,926		305,359
	Fuel, Materials, Supplies and Inventory			292,547		336,476
	Regulatory Assets			863,360		845,843
	Prepayments and Other Current Assets			106,561		129,034
Total Current Assets				2,415,284		2,618,786
Property, Plant and Equipment, Net				20,448,475		19,892,441
Deferred Debits and Other Assets:
	Regulatory Assets			3,661,578		3,737,960
	Goodwill			3,519,401		3,519,401
	Marketable Securities			518,750		516,478
	Other Long-Term Assets			319,175		295,243
Total Deferred Debits and Other Assets				8,018,904		8,069,082
Total Assets			$	30,882,663	$	30,580,309
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable		$	767,000	$	1,160,953
	Long-Term Debt - Current Portion			178,883		228,883
	Accounts Payable			631,566		813,646
	Obligations to Third Party Suppliers			133,943		128,564
	Regulatory Liabilities			119,413		107,759
	Other Current Liabilities			472,964		549,985
Total Current Liabilities				2,303,769		2,989,790
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes			5,398,926		5,147,678
	Regulatory Liabilities			527,678		513,595
	Derivative Liabilities			381,572		337,102
	Accrued Pension, SERP and PBOP			1,294,548		1,407,288
	Other Long-Term Liabilities			875,270		871,499
Total Deferred Credits and Other Liabilities				8,477,994		8,277,162
Capitalization:
	Long-Term Debt			9,435,924		8,805,574
	Noncontrolling Interest - Preferred Stock of Subsidiaries			155,568		155,568
	Equity:
	Common Shareholders' Equity:
		Common Shares		1,669,392		1,669,313
		Capital Surplus, Paid In		6,252,514		6,262,368
		Retained Earnings		2,962,843		2,797,355
		Accumulated Other Comprehensive Loss		(65,364)		(66,844)
		Treasury Stock		(309,977)		(309,977)
	Common Shareholders' Equity			10,509,408		10,352,215
Total Capitalization				20,100,900		19,313,357
Total Liabilities and Capitalization			$	30,882,663	$	30,580,309
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

1

EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
			For the Three Months Ended June 30,				For the Six Months Ended June 30,
(Thousands of Dollars, Except Share Information)			2016		2015		2016		2015
Operating Revenues			$	1,767,184	$	1,817,061	$	3,822,819	$	4,330,491
Operating Expenses:
	Purchased Power, Fuel and Transmission			581,260		685,118		1,336,119		1,847,167
	Operations and Maintenance			320,714		316,641		640,850		650,024
	Depreciation			176,507		163,668		350,492		327,505
	Amortization of Regulatory (Liabilities)/Assets, Net			(8,716)		(1,166)		12,281		59,438
	Energy Efficiency Programs			119,667		101,850		256,842		248,452
	Taxes Other Than Income Taxes			154,330		138,935		314,277		288,415
		Total Operating Expenses		1,343,762		1,405,046		2,910,861		3,421,001
Operating Income				423,422		412,015		911,958		909,490
Interest Expense				100,492		92,259		198,703		187,102
Other Income, Net				8,038		12,899		10,049		18,626
Income Before Income Tax Expense				330,968		332,655		723,304		741,014
Income Tax Expense				125,439		123,268		271,742		276,494
Net Income				205,529		209,387		451,562		464,520
Net Income Attributable to Noncontrolling Interests				1,880		1,880		3,759		3,759
Net Income Attributable to Common Shareholders			$	203,649	$	207,507	$	447,803	$	460,761
Basic and Diluted Earnings Per Common Share			$	0.64	$	0.65	$	1.41	$	1.45
Dividends Declared Per Common Share			$	0.45	$	0.42	$	0.89	$	0.84
Weighted Average Common Shares Outstanding:
	Basic			317,785,495		317,613,166		317,651,319		317,352,004
	Diluted			318,476,699		318,559,568		318,478,876		318,525,378
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	205,529	$	209,387	$	451,562	$	464,520
Other Comprehensive (Loss)/Income, Net of Tax:
	Qualified Cash Flow Hedging Instruments			534		509		1,068		1,018
	Changes in Unrealized Gains/(Losses) on Marketable Securities			1,061		(1,248)		1,325		(1,116)
	Changes in Funded Status of Pension, SERP and PBOP Benefit Plans			(1,784)		1,120		(913)		2,074
Other Comprehensive (Loss)/Income, Net of Tax				(189)		381		1,480		1,976
Comprehensive Income Attributable to Noncontrolling Interests				(1,880)		(1,880)		(3,759)		(3,759)
Comprehensive Income Attributable to Common Shareholders			$	203,460	$	207,888	$	449,283	$	462,737
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

2

EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
			For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015
Operating Activities:
	Net Income		$	451,562	$	464,520
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
		Depreciation		350,492		327,505
		Deferred Income Taxes		250,851		176,800
		Pension, SERP and PBOP Expense		22,659		48,432
		Pension and PBOP Contributions		(65,929)		(31,032)
		Regulatory Underrecoveries, Net		(5,768)		(73,547)
		Amortization of Regulatory Assets, Net		12,281		59,438
		Other		(10,808)		(38,521)
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(76,751)		(123,984)
		Fuel, Materials, Supplies and Inventory		43,930		60,044
		Taxes Receivable/Accrued, Net		230,075		214,577
		Accounts Payable		(151,996)		(228,176)
		Other Current Assets and Liabilities, Net		(72,160)		9,226
Net Cash Flows Provided by Operating Activities				978,438		865,282
Investing Activities:
	Investments in Property, Plant and Equipment			(869,168)		(740,379)
	Proceeds from Sales of Marketable Securities			327,581		427,990
	Purchases of Marketable Securities			(322,244)		(408,242)
	Other Investing Activities			(2,991)		4,821
Net Cash Flows Used in Investing Activities				(866,822)		(715,810)
Financing Activities:
	Cash Dividends on Common Shares			(282,314)		(264,936)
	Cash Dividends on Preferred Stock			(3,759)		(3,759)
	Decrease in Notes Payable			(393,953)		(449,375)
	Issuance of Long-Term Debt			800,000		750,000
	Retirements of Long-Term Debt			(200,000)		(166,577)
	Other Financing Activities			(16,811)		(17,059)
Net Cash Flows Used in Financing Activities				(96,837)		(151,706)
Net Increase/(Decrease) in Cash and Cash Equivalents				14,779		(2,234)
Cash and Cash Equivalents - Beginning of Period				23,947		38,703
Cash and Cash Equivalents - End of Period			$	38,726	$	36,469
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

3

THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED BALANCE SHEETS
(Unaudited)
			June 30,		December 31,
(Thousands of Dollars)			2016		2015
ASSETS
Current Assets:
	Cash		$	9,449	$	1,057
	Receivables, Net			370,982		352,536
	Accounts Receivable from Affiliated Companies			9,703		21,214
	Unbilled Revenues			99,822		99,879
	Taxes Receivable			12,498		137,643
	Regulatory Assets			312,160		268,318
	Materials and Supplies			52,538		43,124
	Prepayments and Other Current Assets			15,826		32,234
Total Current Assets				882,978		956,005
Property, Plant and Equipment, Net				7,336,577		7,156,809
Deferred Debits and Other Assets:
	Regulatory Assets			1,368,897		1,369,028
	Other Long-Term Assets			121,477		111,115
Total Deferred Debits and Other Assets				1,490,374		1,480,143
Total Assets			$	9,709,929	$	9,592,957
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable to Eversource Parent		$	93,000	$	277,400
	Long-Term Debt - Current Portion			150,000		-
	Accounts Payable			219,332		267,764
	Accounts Payable to Affiliated Companies			60,169		66,456
	Obligations to Third Party Suppliers			61,532		60,746
	Regulatory Liabilities			63,287		61,155
	Derivative Liabilities			91,603		91,820
	Other Current Liabilities			122,886		110,631
Total Current Liabilities				861,809		935,972
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes			1,922,428		1,820,865
	Regulatory Liabilities			80,617		74,830
	Derivative Liabilities			380,643		336,189
	Accrued Pension, SERP and PBOP			247,419		271,056
	Other Long-Term Liabilities			131,883		133,446
Total Deferred Credits and Other Liabilities				2,762,990		2,636,386
Capitalization:
	Long-Term Debt			2,614,878		2,763,682
	Preferred Stock Not Subject to Mandatory Redemption			116,200		116,200
	Common Stockholder's Equity:
		Common Stock		60,352		60,352
		Capital Surplus, Paid In		2,056,389		1,910,663
		Retained Earnings		1,237,620		1,170,278
		Accumulated Other Comprehensive Loss		(309)		(576)
	Common Stockholder's Equity			3,354,052		3,140,717
Total Capitalization				6,085,130		6,020,599
Total Liabilities and Capitalization			$	9,709,929	$	9,592,957
The accompanying notes are an integral part of these unaudited condensed financial statements.

4

THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF INCOME
(Unaudited)
			For the Three Months Ended June 30,				For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015		2016		2015
Operating Revenues			$	679,787	$	666,554	$	1,415,103	$	1,471,471
Operating Expenses:
	Purchased Power and Transmission			234,504		253,180		507,104		586,799
	Operations and Maintenance			122,532		118,687		233,375		236,044
	Depreciation			57,532		52,191		114,500		105,094
	Amortization of Regulatory (Liabilities)/Assets, Net			(2,988)		(7,530)		6,891		40,776
	Energy Efficiency Programs			35,498		33,963		73,589		76,770
	Taxes Other Than Income Taxes			70,568		62,102		146,030		130,181
		Total Operating Expenses		517,646		512,593		1,081,489		1,175,664
Operating Income				162,141		153,961		333,614		295,807
Interest Expense				35,978		36,124		72,477		72,748
Other Income, Net				6,275		4,062		7,211		6,221
Income Before Income Tax Expense				132,438		121,899		268,348		229,280
Income Tax Expense				49,563		43,129		98,427		81,276
Net Income			$	82,875	$	78,770	$	169,921	$	148,004
The accompanying notes are an integral part of these unaudited condensed financial statements.
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	82,875	$	78,770	$	169,921	$	148,004
Other Comprehensive Income, Net of Tax:
	Qualified Cash Flow Hedging Instruments			111		111		222		222
	Changes in Unrealized Gains/(Losses) on Marketable Securities			36		(43)		45		(39)
Other Comprehensive Income, Net of Tax				147		68		267		183
Comprehensive Income			$	83,022	$	78,838	$	170,188	$	148,187
The accompanying notes are an integral part of these unaudited condensed financial statements.

5

THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
			For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015
Operating Activities:
	Net Income		$	169,921	$	148,004
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
	Depreciation			114,500		105,094
		Deferred Income Taxes		97,913		30,145
		Pension, SERP, and PBOP Expense, Net of PBOP Contributions		3,325		7,079
		Regulatory Underrecoveries, Net		(40,386)		(55,302)
		Amortization of Regulatory Assets, Net		6,891		40,776
		Other		(4,477)		(2,432)
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(26,729)		(73,279)
		Taxes Receivable/Accrued, Net		145,852		123,051
		Accounts Payable		(38,137)		(55,192)
		Other Current Assets and Liabilities, Net		774		2,085
Net Cash Flows Provided by Operating Activities				429,447		270,029
Investing Activities:
	Investments in Property, Plant and Equipment			(288,630)		(242,346)
	Proceeds from the Sale of  Property, Plant and Equipment			9,047		-
	Other Investing Activities			205		(1,362)
Net Cash Flows Used in Investing Activities				(279,378)		(243,708)
Financing Activities:
	Cash Dividends on Common Stock			(99,800)		(98,000)
	Cash Dividends on Preferred Stock			(2,779)		(2,779)
	Capital Contributions from Eversource Parent			145,700		-
	Issuance of Long-Term Debt			-		300,000
	Retirement of Long-Term Debt			-		(162,000)
	Decrease in Notes Payable to Eversource Parent			(184,400)		(47,800)
	Other Financing Activities			(398)		(8,871)
Net Cash Flows Used in Financing Activities				(141,677)		(19,450)
Net Increase in Cash				8,392		6,871
Cash - Beginning of Period				1,057		2,356
Cash - End of Period			$	9,449	$	9,227
The accompanying notes are an integral part of these unaudited condensed financial statements.

6

NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
			June 30,		December 31,
(Thousands of Dollars)			2016		2015
ASSETS
Current Assets:
	Cash and Cash Equivalents		$	3,391	$	3,346
	Receivables, Net			254,376		229,936
	Accounts Receivable from Affiliated Companies			12,241		4,034
	Unbilled Revenues			43,115		29,464
	Taxes Receivable			21,564		70,236
	Materials, Supplies and Inventory			40,292		75,487
	Regulatory Assets			316,715		348,408
	Prepayments and Other Current Assets			9,510		11,448
Total Current Assets				701,204		772,359
Property, Plant and Equipment, Net				5,788,659		5,655,458
Deferred Debits and Other Assets:
	Regulatory Assets			1,112,099		1,112,977
	Other Long-Term Assets			61,886		62,467
Total Deferred Debits and Other Assets				1,173,985		1,175,444
Total Assets			$	7,663,848	$	7,603,261
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable		$	329,000	$	62,500
	Long-Term Debt - Current Portion			-		200,000
	Accounts Payable			146,868		228,250
	Accounts Payable to Affiliated Companies			46,174		38,648
	Obligations to Third Party Suppliers			61,538		56,718
	Renewable Portfolio Standards Compliance Obligations			44,239		104,847
	Regulatory Liabilities			6,923		3,281
	Other Current Liabilities			58,770		72,007
Total Current Liabilities				693,512		766,251
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes			1,809,408		1,760,339
	Regulatory Liabilities			267,809		264,352
	Accrued Pension, SERP and PBOP			194,734		209,153
	Other Long-Term Liabilities			124,877		120,939
Total Deferred Credits and Other Liabilities				2,396,828		2,354,783
Capitalization:
	Long-Term Debt			2,077,687		1,829,766
	Preferred Stock Not Subject to Mandatory Redemption			43,000		43,000
	Common Stockholder's Equity:
		Common Stock		-		-
		Capital Surplus, Paid In		995,378		995,378
		Retained Earnings		1,456,919		1,613,538
		Accumulated Other Comprehensive Income		524		545
	Common Stockholder's Equity			2,452,821		2,609,461
Total Capitalization				4,573,508		4,482,227
Total Liabilities and Capitalization			$	7,663,848	$	7,603,261
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

7

NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
			For the Three Months Ended June 30,				For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015		2016		2015
Operating Revenues			$	591,301	$	617,196	$	1,205,517	$	1,384,004
Operating Expenses:
	Purchased Power and Transmission			219,189		283,129		473,525		684,995
	Operations and Maintenance			88,954		69,430		183,650		145,254
	Depreciation			52,571		48,949		104,457		97,716
	Amortization of Regulatory Assets/(Liabilities), Net			3,971		(7,336)		8,654		(12,901)
	Energy Efficiency Programs			61,922		41,733		128,165		97,150
	Taxes Other Than Income Taxes			34,194		29,876		66,750		60,841
		Total Operating Expenses		460,801		465,781		965,201		1,073,055
Operating Income				130,500		151,415		240,316		310,949
Interest Expense				20,216		17,781		41,104		38,227
Other Income, Net				2,836		2,533		2,502		3,136
Income Before Income Tax Expense				113,120		136,167		201,714		275,858
Income Tax Expense				44,953		54,204		79,053		110,335
Net Income			$	68,167	$	81,963	$	122,661	$	165,523
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	68,167	$	81,963	$	122,661	$	165,523
Other Comprehensive Loss, Net of Tax:
	Changes in Funded Status of SERP Benefit Plan			(11)		(2)		(21)		(182)
Other Comprehensive Loss, Net of Tax				(11)		(2)		(21)		(182)
Comprehensive Income			$	68,156	$	81,961	$	122,640	$	165,341
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

8

NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
			For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015
Operating Activities:
	Net Income		$	122,661	$	165,523
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
		Depreciation		104,457		97,716
		Deferred Income Taxes		48,505		61,734
		Pension and PBOP Contributions, Net of Pension, SERP and PBOP Expense		(13,236)		(264)
		Regulatory Over/(Under) Recoveries, Net		26,277		(96,290)
		Amortization of Regulatory Assets/(Liabilities), Net		8,654		(12,901)
		Other		(3,978)		(28,653)
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(56,140)		(91,753)
		Materials, Supplies and Inventory		35,194		17,595
		Taxes Receivable/Accrued, Net		45,608		100,661
		Accounts Payable		(88,774)		(30,839)
		Other Current Assets and Liabilities, Net		(64,084)		25,076
Net Cash Flows Provided by Operating Activities				165,144		207,605
Investing Activities:
	Investments in Property, Plant and Equipment			(199,824)		(188,103)
	Other Investing Activities			-		53
Net Cash Flows Used in Investing Activities				(199,824)		(188,050)
Financing Activities:
	Cash Dividends on Common Stock			(278,300)		(99,000)
	Cash Dividends on Preferred Stock			(980)		(980)
	Increase in Notes Payable			266,500		75,200
	Issuance of Long-Term Debt			250,000		-
	Retirements of Long-Term Debt			(200,000)		(4,700)
	Other Financing Activities			(2,495)		-
Net Cash Flows Provided by/(Used in) Financing Activities				34,725		(29,480)
Increase/(Decrease) in Cash and Cash Equivalents				45		(9,925)
Cash and Cash Equivalents - Beginning of Period				3,346		12,773
Cash and Cash Equivalents - End of Period			$	3,391	$	2,848
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

9

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
			June 30,		December 31,
(Thousands of Dollars)			2016		2015
ASSETS
Current Assets:
	Cash		$	1,084	$	1,733
	Receivables, Net			77,389		77,546
	Accounts Receivable from Affiliated Companies			3,938		2,352
	Unbilled Revenues			38,275		38,207
	Taxes Receivable			8,848		43,128
	Fuel, Materials, Supplies and Inventory			151,475		156,868
	Regulatory Assets			122,879		104,971
	Prepayments and Other Current Assets			19,570		24,302
Total Current Assets				423,458		449,107
Property, Plant and Equipment, Net				2,925,288		2,855,363
Deferred Debits and Other Assets:
	Regulatory Assets			238,612		257,873
	Other Long-Term Assets			34,886		34,176
Total Deferred Debits and Other Assets				273,498		292,049
Total Assets			$	3,622,244	$	3,596,519
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable to Eversource Parent		$	120,900	$	231,300
	Accounts Payable			96,059		87,925
	Accounts Payable to Affiliated Companies			21,049		24,214
	Regulatory Liabilities			5,986		6,898
	Other Current Liabilities			37,264		43,921
Total Current Liabilities				281,258		394,258
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes			746,785		705,894
	Regulatory Liabilities			47,283		47,851
	Accrued Pension, SERP and PBOP			75,721		89,579
	Other Long-Term Liabilities			50,318		50,746
Total Deferred Credits and Other Liabilities				920,107		894,070
Capitalization:
	Long-Term Debt			1,071,532		1,071,017
	Common Stockholder's Equity:
		Common Stock		-		-
		Capital Surplus, Paid In		831,634		748,634
		Retained Earnings		523,414		494,901
		Accumulated Other Comprehensive Loss		(5,701)		(6,361)
	Common Stockholder's Equity			1,349,347		1,237,174
Total Capitalization				2,420,879		2,308,191
Total Liabilities and Capitalization			$	3,622,244	$	3,596,519
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

10

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
			For the Three Months Ended June 30,				For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015		2016		2015
Operating Revenues			$	218,517	$	241,875	$	460,807	$	526,722
Operating Expenses:
	Purchased Power, Fuel and Transmission			45,653		47,938		95,867		147,516
	Operations and Maintenance			63,788		76,468		123,001		134,895
	Depreciation			28,644		25,751		56,879		51,397
	Amortization of Regulatory (Liabilities)/Assets, Net			(8,186)		12,050		332		27,181
	Energy Efficiency Programs			3,259		3,356		6,879		7,128
	Taxes Other Than Income Taxes			22,287		22,249		44,082		41,331
		Total Operating Expenses		155,445		187,812		327,040		409,448
Operating Income				63,072		54,063		133,767		117,274
Interest Expense				12,526		11,662		24,987		22,935
Other Income, Net				282		1,245		432		1,628
Income Before Income Tax Expense				50,828		43,646		109,212		95,967
Income Tax Expense				19,573		15,701		41,899		35,977
Net Income			$	31,255	$	27,945	$	67,313	$	59,990
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	31,255	$	27,945	$	67,313	$	59,990
Other Comprehensive Income, Net of Tax:
	Qualified Cash Flow Hedging Instruments			291		290		581		581
	Changes in Unrealized Gains/(Losses) on Marketable Securities			63		(75)		79		(67)
Other Comprehensive Income, Net of Tax				354		215		660		514
Comprehensive Income			$	31,609	$	28,160	$	67,973	$	60,504
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

11

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
			For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015
Operating Activities:
	Net Income		$	67,313	$	59,990
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
		Depreciation		56,879		51,397
		Deferred Income Taxes		45,976		47,454
		Regulatory Underrecoveries, Net		(10,740)		(3,089)
		Amortization of Regulatory Assets, Net		332		27,181
		Other		(8,484)		8,726
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(5,247)		(6,597)
		Fuel, Materials, Supplies and Inventory		5,394		11,019
		Taxes Receivable/Accrued, Net		33,840		(20,414)
		Accounts Payable		20,417		(21,362)
		Other Current Assets and Liabilities, Net		(1,422)		(3,792)
Net Cash Flows Provided by Operating Activities				204,258		150,513
Investing Activities:
	Investments in Property, Plant and Equipment			(138,713)		(140,171)
	Other Investing Activities			172		169
Net Cash Flows Used in Investing Activities				(138,541)		(140,002)
Financing Activities:
	Cash Dividends on Common Stock			(38,800)		(53,000)
	Capital Contributions from Eversource Parent			83,000		-
	(Decrease)/Increase in Notes Payable to Eversource Parent			(110,400)		43,000
	Other Financing Activities			(166)		(182)
Net Cash Flows Used in Financing Activities				(66,366)		(10,182)
Net (Decrease)/Increase in Cash				(649)		329
Cash - Beginning of Period				1,733		489
Cash - End of Period			$	1,084	$	818
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

12

WESTERN MASSACHUSETTS ELECTRIC COMPANY
CONDENSED BALANCE SHEETS
(Unaudited)
			June 30,		December 31,
(Thousands of Dollars)			2016		2015
ASSETS
Current Assets:
	Cash		$	1,421	$	834
	Receivables, Net			54,685		50,912
	Accounts Receivable from Affiliated Companies			9,139		18,633
	Unbilled Revenues			13,928		15,065
	Taxes Receivable			422		33,407
	Regulatory Assets			57,660		56,166
	Prepayments and Other Current Assets			8,598		7,882
Total Current Assets				145,853		182,899
Property, Plant and Equipment, Net				1,616,305		1,575,306
Deferred Debits and Other Assets:
	Regulatory Assets			124,804		135,010
	Other Long-Term Assets			27,625		24,875
Total Deferred Debits and Other Assets				152,429		159,885
Total Assets			$	1,914,587	$	1,918,090
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable to Eversource Parent		$	53,700	$	143,400
	Accounts Payable			32,783		58,364
	Accounts Payable to Affiliated Companies			19,935		19,896
	Obligations to Third Party Suppliers			10,336		9,654
	Renewable Portfolio Standards Compliance Obligations			11,251		6,395
	Regulatory Liabilities			11,256		13,122
	Other Current Liabilities			11,556		13,878
Total Current Liabilities				150,817		264,709
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes			487,389		470,539
	Regulatory Liabilities			13,280		11,597
	Accrued Pension, SERP and PBOP			12,135		19,515
	Other Long-Term Liabilities			40,175		36,819
Total Deferred Credits and Other Liabilities				552,979		538,470
Capitalization:
	Long-Term Debt			566,885		517,329
	Common Stockholder's Equity:
		Common Stock		10,866		10,866
		Capital Surplus, Paid In		426,398		391,398
		Retained Earnings		209,232		198,140
		Accumulated Other Comprehensive Loss		(2,590)		(2,822)
	Common Stockholder's Equity			643,906		597,582
Total Capitalization				1,210,791		1,114,911
Total Liabilities and Capitalization			$	1,914,587	$	1,918,090
The accompanying notes are an integral part of these unaudited condensed financial statements.

13

WESTERN MASSACHUSETTS ELECTRIC COMPANY
CONDENSED STATEMENTS OF INCOME
(Unaudited)
			For the Three Months Ended June 30,				For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015		2016		2015
Operating Revenues			$	116,396	$	125,194	$	244,491	$	278,058
Operating Expenses:
	Purchased Power and Transmission			32,665		43,055		72,228		112,716
	Operations and Maintenance			22,088		20,104		43,893		39,889
	Depreciation			11,476		10,848		22,847		21,223
	Amortization of Regulatory Assets, Net			992		3,336		2,203		7,264
	Energy Efficiency Programs			10,347		9,519		21,203		20,594
	Taxes Other Than Income Taxes			9,600		9,398		19,833		18,833
		Total Operating Expenses		87,168		96,260		182,207		220,519
Operating Income				29,228		28,934		62,284		57,539
Interest Expense				6,072		6,291		12,075		13,112
Other Income/(Loss), Net				104		1,245		(46)		1,819
Income Before Income Tax Expense				23,260		23,888		50,163		46,246
Income Tax Expense				9,995		9,693		20,071		18,807
Net Income			$	13,265	$	14,195	$	30,092	$	27,439
The accompanying notes are an integral part of these unaudited condensed financial statements.
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	13,265	$	14,195	$	30,092	$	27,439
Other Comprehensive Income, Net of Tax:
	Qualified Cash Flow Hedging Instruments			110		84		219		169
	Changes in Unrealized Gains/(Losses) on Marketable Securities			10		(12)		13		(11)
Other Comprehensive Income, Net of Tax				120		72		232		158
Comprehensive Income			$	13,385	$	14,267	$	30,324	$	27,597
The accompanying notes are an integral part of these unaudited condensed financial statements.

14

WESTERN MASSACHUSETTS ELECTRIC COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
			For the Six Months Ended June 30,
(Thousands of Dollars)			2016		2015
Operating Activities:
	Net Income		$	30,092	$	27,439
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
		Depreciation		22,847		21,223
		Deferred Income Taxes		17,155		12,503
		Regulatory Underrecoveries, Net		(2,651)		(7,911)
		Amortization of Regulatory Assets, Net		2,203		7,264
		Other		(2,547)		(3,598)
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		6,500		(11,593)
		Taxes Receivable/Accrued, Net		32,985		18,774
		Accounts Payable		(13,176)		(21,056)
		Other Current Assets and Liabilities, Net		2,502		859
Net Cash Flows Provided by Operating Activities				95,910		43,904
Investing Activities:
	Investments in Property, Plant and Equipment			(71,459)		(62,966)
	Proceeds from Sales of Marketable Securities			1,484		49,739
	Purchases of Marketable Securities			(1,457)		(50,118)
Net Cash Flows Used in Investing Activities				(71,432)		(63,345)
Financing Activities:
	Cash Dividends on Common Stock			(19,000)		(18,600)
	Capital Contribution from Eversource Parent			35,000		-
	(Decrease)/Increase in Notes Payable to Eversource Parent			(89,700)		39,200
	Issuance of Long-Term Debt			50,000		-
	Other Financing Activities			(191)		(16)
Net Cash Flows (Used in)/Provided by Financing Activities				(23,891)		20,584
Net Increase in Cash				587		1,143
Cash - Beginning of Period				834		-
Cash - End of Period			$	1,421	$	1,143
The accompanying notes are an integral part of these unaudited condensed financial statements.

15

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 regulated utility subsidiaries, in the energy delivery business.  Eversource Energy's wholly owned regulated utility subsidiaries consist of CL&P, NSTAR Electric, PSNH, WMECO, Yankee Gas and NSTAR Gas.  Eversource provides energy delivery service to approximately 3.6 million electric and natural gas customers through these six regulated utilities in Connecticut, Massachusetts and New Hampshire.  

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 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 Statements and Supplementary Data," of the Eversource 2015 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, CL&P's, NSTAR Electric's, PSNH's and WMECO's financial position as of June 30, 2016 and December 31, 2015, the results of operations and comprehensive income for the three and six months ended June 30, 2016 and 2015, and the cash flows for the six months ended June 30, 2016 and 2015.  The results of operations and comprehensive income for the three and six months ended June 30, 2016 and 2015 and the cash flows for the six months ended June 30, 2016 and 2015 are not necessarily indicative of the results expected for a full year.  

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

Access Northeast is a natural gas pipeline and storage project (the "Project") being developed jointly by Eversource, Spectra Energy Corp and National Grid. Access Northeast will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes.  Eversource and Spectra Energy Corp each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid.  The total projected cost for both the pipeline and the LNG storage is expected to be approximately $3 billion, to be funded in proportion to ownership interest (approximately $1.2 billion by Eversource), with anticipated in-service dates commencing in November 2018.  Eversource’s cumulative equity investment in the Project as of June 30, 2016 of $20.7 million is presented in Other Long-Term Assets.  

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

Certain reclassifications of prior 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.

B.

Accounting Standards

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

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In January 2016, the FASB issued ASU 2016-01, Financial Instruments - Overall: Recognition and Measurement of Financial Assets and Liabilities, which is required to be implemented in the first quarter of 2018.  The Company is reviewing the requirements of the ASU.  The ASU will remove the available-for-sale designation for equity securities, whereby changes in fair value are recorded in other comprehensive income in shareholders' equity, and will require changes in fair value of all equity securities to be recorded in earnings beginning on January 1, 2018, with the unrealized gain or loss on available-for-sale equity securities as of that date reclassified to retained earnings as a cumulative effect of adoption.  The fair value of available-for-sale equity securities subject to this guidance as of June 30, 2016 was approximately $48 million.  The remaining available-for-sale equity securities included in marketable securities on the balance sheet are held in nuclear decommissioning trusts and are subject to regulatory accounting treatment and will not be impacted by this guidance.  Implementation of the ASU for other financial instruments is not expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

In February 2016, the FASB issued ASU 2016-02, Leases, which changes existing lease accounting guidance and is required to be applied in the first quarter of 2019, with earlier application permitted.  The ASU is required to be implemented for leases beginning on the date of initial application.  For prior periods presented, leases are required to be recognized and measured using a modified retrospective approach.  The Company is reviewing the requirements of ASU 2016-02, including balance sheet recognition of leases previously deemed operating leases, and expects to implement them in the first quarter of 2019.  

Recently Adopted Accounting Standards:  In April 2015, the FASB issued ASU 2015-05, Intangibles – Goodwill and Other – Internal-Use Software: Customer's Accounting for Fees Paid in a Cloud Computing Arrangement, effective for annual periods, including interim periods, beginning after December 15, 2015.  The ASU amends existing guidance on intangibles and internal-use software and may be applied prospectively or retrospectively.  On January 1, 2016, Eversource adopted the new accounting guidance prospectively, which did not have an impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

In March 2016, the FASB issued ASU 2016-09, Compensation - Stock Compensation: Improvements to Employee Share-Based Payment Accounting.  The ASU is intended to simplify some aspects of the accounting for share-based payment transactions.  The ASU is required to be implemented in the first quarter of 2017, with early adoption permitted.  The Company implemented this guidance in the first quarter of 2016.  Beginning in the first quarter of 2016, the excess tax benefits associated with the distribution of stock compensation awards, previously recognized in Capital Surplus, Paid In in Common Shareholders' Equity on the balance sheet, are recognized in income tax expense in the income statement.  The implementation reduced income tax expense by $2.7 million for the six months ended June 30, 2016.  Also, beginning in 2016, in the statement of cash flows, the excess tax benefits are presented as an operating activity rather than 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 six months ended June 30, 2016 and 2015 were $9.1 million and $9.7 million, respectively, and are included in Other Financing Activities on the statements of cash flows.  

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 assessment of collectability from customers.  Management continuously assesses the collectability of receivables and adjusts collectability estimates based on actual experience.  Receivable balances are written off against the provision for uncollectible accounts when the customer accounts are terminated and these balances are deemed to be uncollectible.

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

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

	Total Provision for Uncollectible Accounts				Uncollectible Hardship
(Millions of Dollars)	As of June 30, 2016		As of December 31, 2015		As of June 30, 2016		As of December 31, 2015
Eversource	$	205.5	$	190.7	$	123.7	$	118.5
CL&P		82.7		79.5		66.2		68.1
NSTAR Electric		56.9		52.6		28.6		25.3
PSNH		9.6		8.7		-		-
WMECO		15.3		14.0		8.4		7.4

D.

Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases or normal sales" (normal) and to the marketable securities held in trusts.  Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill and AROs, and the estimated fair value of preferred stock and long-term debt.

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

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

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

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

Determination of Fair Value:  The valuation techniques and inputs used in Eversource's fair value measurements are described in Note 4, "Derivative Instruments," Note 5, "Marketable Securities," and Note 9, "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 equity method investees.  Investment income/(loss) primarily relates to debt and equity securities held in trust.  For further information, see Note 5, "Marketable Securities," to the financial statements.  

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 Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015		June 30, 2016		June 30, 2015
Eversource	$	37.5	$	33.2	$	79.8	$	75.1
CL&P		33.6		29.5		69.6		62.5

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

G. Supplemental Cash Flow Information
Non-cash investing activities include plant additions included in Accounts Payable as follows:
(Millions of Dollars)	As of June 30, 2016		As of June 30, 2015
Eversource	$	186.3	$	142.3
CL&P		59.5		47.2
NSTAR Electric		38.5		29.5
PSNH		31.1		25.6
WMECO		14.6		13.7

2.

REGULATORY ACCOUNTING

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

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

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

	As of June 30, 2016		As of December 31, 2015
(Millions of Dollars)	Eversource		Eversource
Benefit Costs	$	1,754.1	$	1,828.2
Derivative Liabilities		413.7		388.0
Income Taxes, Net		644.3		650.9
Storm Restoration Costs		428.9		436.9
Goodwill-related		474.6		484.9
Regulatory Tracker Mechanisms		562.5		526.5
Contractual Obligations - Yankee Companies		117.3		134.4
Other Regulatory Assets		129.6		134.0
Total Regulatory Assets		4,525.0		4,583.8
Less:  Current Portion		863.4		845.8
Total Long-Term Regulatory Assets	$	3,661.6	$	3,738.0

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Benefit Costs	$	383.2	$	477.0	$	160.0	$	77.9	$	413.6	$	479.9	$	164.2	$	84.9
Derivative Liabilities		411.3		2.4		-		-		380.8		1.3		-		-
Income Taxes, Net		442.5		86.3		28.2		31.0		444.4		85.7		34.5		31.8
Storm Restoration Costs		269.5		117.7		21.7		20.0		271.4		110.9		31.5		23.1
Goodwill-related		-		407.5		-		-		-		416.3		-		-
Regulatory Tracker Mechanisms		96.6		287.0		120.5		41.5		45.1		311.0		101.2		40.1
Other Regulatory Assets		78.0		50.9		31.1		12.1		82.0		56.3		31.5		11.3
Total Regulatory Assets		1,681.1		1,428.8		361.5		182.5		1,637.3		1,461.4		362.9		191.2
Less:  Current Portion		312.2		316.7		122.9		57.7		268.3		348.4		105.0		56.2
Total Long-Term Regulatory Assets	$	1,368.9	$	1,112.1	$	238.6	$	124.8	$	1,369.0	$	1,113.0	$	257.9	$	135.0

Regulatory Costs in Other Long-Term Assets:  The Regulated companies had $83 million (including $2.6 million for CL&P, $38.5 million for NSTAR Electric, $5.5 million for PSNH and $19.4 million for WMECO) and $75.3 million (including $3.1 million for CL&P, $35.4 million for NSTAR Electric, $4.8 million for PSNH, and $16.7 million for WMECO) of additional regulatory costs as of June 30, 2016 and December 31, 2015, 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 June 30, 2016		As of December 31, 2015
(Millions of Dollars)	Eversource		Eversource
Cost of Removal	$	448.5	$	437.1
Regulatory Tracker Mechanisms		104.4		99.7
AFUDC - Transmission		65.7		66.1
Other Regulatory Liabilities		28.5		18.5
Total Regulatory Liabilities		647.1		621.4
Less:  Current Portion		119.4		107.8
Total Long-Term Regulatory Liabilities	$	527.7	$	513.6

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Cost of Removal	$	30.4	$	261.6	$	46.6	$	4.6	$	24.1	$	257.4	$	47.2	$	2.8
Regulatory Tracker Mechanisms		50.0		6.1		3.2		11.1		56.2		3.3		3.4		12.9
AFUDC - Transmission		50.9		6.0		-		8.8		51.5		5.7		-		8.9
Other Regulatory Liabilities		12.6		1.0		3.5		0.1		4.2		1.3		4.2		0.1
Total Regulatory Liabilities		143.9		274.7		53.3		24.6		136.0		267.7		54.8		24.7
Less:  Current Portion		63.3		6.9		6.0		11.3		61.2		3.3		6.9		13.1
Total Long-Term Regulatory Liabilities	$	80.6	$	267.8	$	47.3	$	13.3	$	74.8	$	264.4	$	47.9	$	11.6

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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 June 30, 2016		As of December 31, 2015
(Millions of Dollars)		Eversource		Eversource
Distribution - Electric		$	13,425.4	$	13,054.8
Distribution - Natural Gas			2,819.9		2,727.2
Transmission - Electric			7,896.3		7,691.9
Generation			1,218.3		1,194.1
Electric and Natural Gas Utility			25,359.9		24,668.0
Other (1)			583.5		558.6
Property, Plant and Equipment, Gross			25,943.4		25,226.6
Less:  Accumulated Depreciation
	Electric and Natural Gas Utility		(6,342.9)		(6,141.1)
	Other		(274.5)		(255.6)
Total Accumulated Depreciation			(6,617.4)		(6,396.7)
Property, Plant and Equipment, Net			19,326.0		18,829.9
Construction Work in Progress			1,122.5		1,062.5
Total Property, Plant and Equipment, Net		$	20,448.5	$	19,892.4

⁽¹⁾

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

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Distribution	$	5,471.5	$	5,279.1	$	1,883.8	$	831.0	$	5,377.2	$	5,100.5	$	1,804.8	$	812.3
Transmission		3,691.2		2,205.3		972.0		977.9		3,618.0		2,131.3		928.2		964.9
Generation		-		-		1,182.4		35.9		-		-		1,158.1		36.0
Property, Plant and    Equipment, Gross		9,162.7		7,484.4		4,038.2		1,844.8		8,995.2		7,231.8		3,891.1		1,813.2
Less:  Accumulated Depreciation		(2,089.2)		(1,962.7)		(1,217.3)		(323.0)		(2,041.9)		(1,886.8)		(1,171.0)		(307.0)
Property, Plant and Equipment, Net		7,073.5		5,521.7		2,820.9		1,521.8		6,953.3		5,345.0		2,720.1		1,506.2
Construction Work in Progress		263.1		267.0		104.4		94.5		203.5		310.5		135.3		69.1
Total Property, Plant and   Equipment, Net	$	7,336.6	$	5,788.7	$	2,925.3	$	1,616.3	$	7,156.8	$	5,655.5	$	2,855.4	$	1,575.3

As of June 30, 2016, PSNH had $1.2 billion in gross generation utility plant assets and related Accumulated Depreciation of $542.8 million.  These generation assets are the subject of a divestiture agreement whereby PSNH agreed to divest of these generation assets.  The NHPUC approved the divestiture agreement on July 1, 2016.  The NHPUC is in the process of selecting an auction adviser to assist with the divestiture.  Upon completion of the divestiture process, all remaining costs not recovered by the sale of these assets (stranded costs) will be recovered via bonds that will be secured by a non-bypassable charge or through recoveries in rates billed to PSNH's customers.  See Note 8E, "Commitments and Contingencies – PSNH Generation Restructuring," for further information.

4.

DERIVATIVE INSTRUMENTS

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

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

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

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

		As of June 30, 2016						As of December 31, 2015
		Commodity Supply				Net Amount		Commodity Supply				Net Amount
		and Price Risk				Recorded as		and Price Risk					Recorded as
(Millions of Dollars)		Management		Netting (1)		a Derivative		Management		Netting (1)		a Derivative
Current Derivative Assets:
Level 2:
	Eversource	$	3.5	$	-	$	3.5	$	-	$	-	$	-
Level 3:
	Eversource		17.5		(10.8)		6.7		16.7		(10.9)		5.8
	CL&P		16.6		(10.8)		5.8		16.7		(10.9)		5.8
	NSTAR Electric		0.9		-		0.9		-		-		-
Long-Term Derivative Assets:
Level 2:
	Eversource	$	-	$	-	$	-	$	0.1	$	-	$	0.1
Level 3:
	Eversource		70.1		(14.8)		55.3		62.0		(19.3)		42.7
	CL&P		69.9		(14.8)		55.1		60.7		(19.3)		41.4
	NSTAR Electric		0.2		-		0.2		1.3		-		1.3
Current Derivative Liabilities:
Level 2:
	Eversource	$	-	$	-	$	-	$	(5.8)	$	-	$	(5.8)
Level 3:
	Eversource		(93.0)		-		(93.0)		(92.3)		-		(92.3)
	CL&P		(91.6)		-		(91.6)		(91.8)		-		(91.8)
	NSTAR Electric		(1.4)		-		(1.4)		(0.5)		-		(0.5)
Long-Term Derivative Liabilities:
Level 3:
	Eversource	$	(381.6)	$	-	$	(381.6)	$	(337.1)	$	-	$	(337.1)
	CL&P		(380.6)		-		(380.6)		(336.2)		-		(336.2)
	NSTAR Electric		(1.0)		-		(1.0)		(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 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 June 30, 2016 and December 31, 2015, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately 7.1 million and 9.1 million MMBtu of natural gas, respectively.

For the three months ended June 30, 2016 and 2015, there were losses of $42.9 million and $36.6 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource's derivative contracts. For the six months ended June 30, 2016 and 2015, these losses were $74.4 million and $50.1 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

21

and energy-related products, and accounting requirements.  The future power and capacity prices for periods that are not quoted in an active market or established at auction are based on available market data and are escalated based on estimates of inflation in order to address the full time period of the contract.  

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

The following is a summary of Eversource's, including CL&P's and NSTAR Electric's, Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts:

	As of June 30, 2016						As of December 31, 2015
		Range				Period Covered		Range				Period Covered
Capacity Prices:
Eversource	$	5.50	-	13.23	per kW-Month	2017 - 2026	$	10.81	-	15.82	per kW-Month	2016 - 2026
CL&P	$	5.50	-	13.23	per kW-Month	2020 - 2026	$	10.81	-	12.60	per kW-Month	2019 - 2026
NSTAR Electric	$	8.50	-	12.11	per kW-Month	2017 - 2018	$	10.81	-	15.82	per kW-Month	2016 - 2019
Forward Reserve:
Eversource, CL&P	$	2.00			per kW-Month	2016 - 2024	$	2.00			per kW-Month	2016 - 2024
REC Prices:
Eversource, NSTAR Electric	$	38	-	42	per REC	2016 - 2018	$	45	-	51	per REC	2016 - 2018

Exit price premiums of 4 percent through 21 percent are also applied on these contracts and reflect the uncertainty and illiquidity premiums that would be required based on the most recent market activity available for similar type contracts.

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 June 30,
	2016						2015
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(387.7)	$	(385.1)	$	(2.6)	$	(406.8)	$	(403.3)	$	(3.5)
Net Realized/Unrealized Gains/(Losses)   Included in Regulatory Assets and Liabilities		(46.6)		(46.8)		0.2		(37.1)		(36.8)		(0.3)
Settlements		21.7		20.6		1.1		21.5		19.9		1.6
Fair Value as of End of Period	$	(412.6)	$	(411.3)	$	(1.3)	$	(422.4)	$	(420.2)	$	(2.2)
	For the Six Months Ended June 30,
	2016						2015
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		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 Losses Included in    Regulatory Assets and Liabilities		(76.6)		(72.2)		(4.4)		(49.2)		(48.9)		(0.3)
Settlements		44.9		41.7		3.2		42.2		39.6		2.6
Fair Value as of End of Period	$	(412.6)	$	(411.3)	$	(1.3)	$	(422.4)	$	(420.2)	$	(2.2)

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 June 30, 2016 and December 31, 2015, these securities were classified as Level 1 in the fair value hierarchy and totaled $10.6 million and $14.2 million, respectively.  For the three months ended June 30, 2016 and 2015, net gains on these securities of $0.2 million and $0.5 million, respectively, and for the six months ended June 30, 2016 and 2015, net gains of $0.5 million and $2.1 million, respectively, were recorded in Other Income, Net on the statements of income.   Dividend income is recorded in Other Income, Net when dividends are declared.  

22

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 June 30, 2016												As of December 31, 2015
					Pre-Tax			Pre-Tax									Pre-Tax			Pre-Tax
Eversource		Amortized			Unrealized			Unrealized						Amortized			Unrealized			Unrealized
(Millions of Dollars)		Cost			Gains			Losses			Fair Value			Cost			Gains			Losses			Fair Value
Debt Securities	$		261.0	$		8.4	$		-	$		269.4	$		256.5	$		4.5	$		(0.6)	$		260.4
Equity Securities			207.8			58.5			(2.3)			264.0			215.3			59.2			(3.4)			271.1

Eversource's debt and equity securities include CYAPC's and YAEC's marketable securities held in nuclear decommissioning trusts of $439.5 million and $436.9 million as of June 30, 2016 and December 31, 2015, 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 six months ended June 30, 2016 and 2015.  Factors considered in determining whether a credit loss exists include the duration and severity of the impairment, adverse conditions specifically affecting the issuer, and the payment history, ratings and rating changes of the security.  For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated.

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

Contractual Maturities:  As of June 30, 2016, the contractual maturities of available-for-sale debt securities were as follows:  

Eversource	Amortized
(Millions of Dollars)	Cost		Fair Value
Less than one year (1)	$	27.2	$	27.2
One to five years		61.6		62.4
Six to ten years		45.4		47.2
Greater than ten years		126.8		132.6
Total Debt Securities	$	261.0	$	269.4

⁽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 June 30, 2016		As of December 31, 2015
Level 1:
	Mutual Funds and Equities	$	274.6	$	285.3
	Money Market Funds		21.1		26.9
Total Level 1		$	295.7	$	312.2
Level 2:
	U.S. Government Issued Debt Securities    (Agency and Treasury)	$	70.8	$	46.6
	Corporate Debt Securities		39.5		43.9
	Asset-Backed Debt Securities		18.8		20.0
	Municipal Bonds		109.9		111.4
	Other Fixed Income Securities		9.3		11.6
Total Level 2		$	248.3	$	233.5
Total Marketable Securities		$	544.0	$	545.7

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.

23

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 June 30, 2016 and December 31, 2015, Eversource parent had $438 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $1.0 billion and $351.5 million of available borrowing capacity as of June 30, 2016 and December 31, 2015, respectively.  The weighted-average interest rate on these borrowings as of June 30, 2016 and December 31, 2015 was 0.66 percent and 0.72 percent, respectively.  As of June 30, 2016, there were intercompany loans from Eversource parent of $93 million to CL&P, $120.9 million to PSNH and $53.7 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 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, which terminates on September 4, 2020.  The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program.  

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 June 30, 2016 and December 31, 2015, NSTAR Electric had $329 million and $62.5 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $121 million and $387.5 million of available borrowing capacity as of June 30, 2016 and December 31, 2015, respectively.  The weighted-average interest rate on these borrowings as of June 30, 2016 and December 31, 2015 was 0.44 percent and 0.40 percent, respectively.  NSTAR Electric is a party to a five-year $450 million revolving credit facility, which terminates on September 4, 2020.  The revolving credit facility serves to backstop NSTAR Electric's $450 million commercial paper program.   

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 balance sheets.

Long-Term Debt Issuances:  In March 2016, Eversource parent issued $250 million of 2.50 percent Series I Senior Notes due to mature in 2021 and $250 million of 3.35 percent Series J Senior Notes due to mature in 2026.  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 issued $250 million of 2.70 percent debentures, 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.  The proceeds, net of issuance costs, were used to repay short-term borrowings.

Long-Term Debt Repayments:  In May 2016, NSTAR Electric repaid at maturity $200 million variable rate debentures, using short-term borrowings.

7.

PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS

Eversource Service sponsors a defined benefit retirement plan (Pension Plan) that covers eligible employees, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO.  In addition to the Pension Plan, Eversource maintains non-qualified defined benefit retirement plans sponsored by Eversource Service (SERP Plans), which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees.  Eversource Service also sponsors defined benefit postretirement plans that provide certain benefits, primarily medical, dental and life insurance, to retired employees that met certain age and service eligibility requirements, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO (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 5.14 percent for the Pension and PBOP plans, respectively. The discount rates used to estimate the 2016 interest cost were 3.80 percent and 3.72 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 June 30, 2016 was approximately $11.5 million and $2.5 million for the Pension and PBOP plans, respectively, and approximately $23 million and $5 million for the six months ended June 30, 2016, respectively.

On August 5, 2016, the Company amended its PBOP plan.  The amendment standardized separate benefit structures that existed within the plan and made other benefit changes.  Overall, the plan amendment is expected to reduce the PBOP plan's accumulated projected benefit obligation by approximately $220 million.  The PBOP liability will be remeasured as of August 5, 2016, and the PBOP expense for the remainder of 2016 will be recorded using updated assumptions and actuarial calculations.

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 portion 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

24

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 Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015(1)		June 30, 2016		June 30, 2015(1)
Service Cost	$	18.7	$	22.8	$	37.9	$	45.9
Interest Cost		46.4		56.9		92.8		113.3
Expected Return on Plan Assets		(79.5)		(83.9)		(159.1)		(168.2)
Actuarial Loss		31.3		36.5		63.0		75.5
Prior Service Cost		0.9		0.9		1.8		1.8
Total Net Periodic Benefit Expense	$	17.8	$	33.2	$	36.4	$	68.3
Capitalized Pension Expense	$	5.4	$	9.8	$	11.4	$	21.1
	PBOP				PBOP
Eversource	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015(1)		June 30, 2016		June 30, 2015(1)
Service Cost	$	3.1	$	3.9	$	6.3	$	8.1
Interest Cost		9.4		11.7		19.0		23.6
Expected Return on Plan Assets		(15.7)		(16.9)		(31.5)		(33.7)
Actuarial Loss		0.9		1.7		2.1		3.4
Prior Service Credit		-		(0.2)		(0.1)		(0.2)
Total Net Periodic Benefit Expense/(Income)	$	(2.3)	$	0.2	$	(4.2)	$	1.2
Capitalized PBOP Expense/(Income)	$	(1.0)	$	(0.1)	$	(1.9)	$	-

	Pension and SERP
	For the Three Months Ended June 30, 2016								For the Three Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	4.6	$	3.3	$	2.5	$	0.8	$	6.2	$	3.7	$	3.1	$	1.0
Interest Cost		10.2		8.5		5.1		2.1		12.9		10.0		6.1		2.6
Expected Return on Plan Assets		(18.0)		(16.9)		(9.6)		(4.4)		(19.8)		(17.5)		(10.1)		(4.7)
Actuarial Loss		6.3		8.7		2.6		1.3		8.0		8.7		2.9		1.6
Prior Service Cost		0.4		-		0.1		0.1		0.4		-		0.1		0.1
Total Net Periodic Benefit Expense/(Income)	$	3.5	$	3.6	$	0.7	$	(0.1)	$	7.7	$	4.9	$	2.1	$	0.6
Intercompany Allocations	$	3.5	$	2.2	$	1.0	$	0.6	$	5.8	$	3.4	$	1.6	$	1.1
Capitalized Pension Expense	$	2.2	$	2.0	$	0.4	$	0.1	$	4.7	$	2.7	$	0.9	$	0.5
	Pension and SERP
	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	9.6	$	6.7	$	5.0	$	1.6	$	12.2	$	7.5	$	6.0	$	2.2
Interest Cost		21.0		16.8		10.3		4.2		25.4		20.1		12.1		5.2
Expected Return on Plan Assets		(36.2)		(33.8)		(19.3)		(8.8)		(39.4)		(35.1)		(20.2)		(9.4)
Actuarial Loss		13.0		17.0		4.9		2.8		16.2		18.4		5.8		3.2
Prior Service Cost		0.8		-		0.2		0.2		0.8		-		0.2		0.1
Total Net Periodic Benefit Expense	$	8.2	$	6.7	$	1.1	$	-	$	15.2	$	10.9	$	3.9	$	1.3
Intercompany Allocations	$	6.8	$	4.5	$	2.0	$	1.2	$	12.2	$	6.9	$	3.4	$	2.3
Capitalized Pension Expense	$	4.9	$	3.7	$	0.7	$	0.2	$	9.4	$	5.9	$	1.7	$	1.0

25

	PBOP
	For the Three Months Ended June 30, 2016								For the Three Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	0.4	$	1.0	$	0.3	$	0.1	$	0.5	$	1.3	$	0.3	$	0.1
Interest Cost		1.3		3.8		0.7		0.3		1.8		4.7		1.0		0.3
Expected Return on Plan Assets		(2.5)		(6.4)		(1.4)		(0.6)		(2.8)		(6.9)		(1.5)		(0.6)
Actuarial Loss		0.3		0.3		0.1		-		0.2		0.4		0.1		-
Prior Service Credit		-		-		-		-		-		(0.1)		-		-
Total Net Periodic Benefit Income	$	(0.5)	$	(1.3)	$	(0.3)	$	(0.2)	$	(0.3)	$	(0.6)	$	(0.1)	$	(0.2)
Intercompany Allocations	$	0.2	$	0.1	$	-	$	-	$	0.4	$	0.2	$	0.1	$	0.1
Capitalized PBOP Income	$	(0.2)	$	(0.6)	$	(0.1)	$	(0.1)	$	(0.1)	$	(0.2)	$	-	$	-
	PBOP
	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
			NSTAR									NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH		WMECO	CL&P			Electric	PSNH (1)		WMECO
Service Cost	$	0.9	$	1.8	$	0.6	$	0.2	$	1.1	$	2.7	$	0.7	$	0.2
Interest Cost		2.7		7.8		1.5		0.5		3.5		9.5		1.9		0.8
Expected Return on Plan Assets		(5.1)		(12.7)		(2.8)		(1.1)		(5.5)		(13.7)		(3.0)		(1.3)
Actuarial Loss		0.5		0.5		0.2		-		0.3		1.2		0.3		-
Prior Service Credit		-		-		-		-		-		(0.1)		-		-
Total Net Periodic Benefit Income	$	(1.0)	$	(2.6)	$	(0.5)	$	(0.4)	$	(0.6)	$	(0.4)	$	(0.1)	$	(0.3)
Intercompany Allocations	$	0.3	$	0.1	$	-	$	0.1	$	0.9	$	0.4	$	0.2	$	0.2
Capitalized PBOP Expense/(Income)	$	(0.5)	$	(1.1)	$	(0.1)	$	(0.2)	$	(0.1)	$	(0.1)	$	0.1	$	(0.1)
(1) Amounts excluded approximately $0.8 million and $1.6 million for the three and six months ended June 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 June 30, 2016				As of December 31, 2015
			Reserve				Reserve
	Number of Sites		(in millions)		Number of Sites		(in millions)
Eversource		63	$	59.5		64	$	51.1
CL&P		14		4.6		14		4.6
NSTAR Electric		14		2.3		15		2.4
PSNH		12		4.4		12		4.5
WMECO		4		0.6		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 $53.7 million and $45.5 million as of June 30, 2016 and December 31, 2015, respectively, and related primarily to the natural gas business segment.

These reserve estimates are subjective in nature as they take into consideration several different remediation options at each specific site.  The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource's, CL&P's, NSTAR Electric's, PSNH's, and WMECO's responsibility for remediation or the extent of remediation required, recently enacted laws and regulations or changes in cost estimates due to certain economic factors.  It is possible that new information or future developments could require a reassessment of the potential exposure to related environmental matters.  As this information becomes available, management will continue to assess the potential exposure and adjust the reserves accordingly.

26

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 a wholly-owned subsidiary to guarantee the payment of the 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 obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations.  Eversource parent has also entered into a guaranty on behalf of NPT under which Eversource parent will guarantee NPT’s obligations under its letter of credit 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 as a result of these various guarantees and indemnifications.  

The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries to external parties, as of June 30, 2016:  

			Maximum Exposure
Company		Description	(in millions)		Expiration Dates
On behalf of subsidiaries:
	Eversource Gas Transmission LLC	Access Northeast Project Capital Contributions Guaranty	$	187.4	2021
	Various	Surety Bonds (1)	$	35.8	2016 - 2018
	Eversource Service and Rocky River Realty Company	Lease Payments for Vehicles and Real Estate	$	10.1	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, awarding 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 by the Yankee Companies in Phase III.  The decision became final on July 18, 2016.  Management cannot predict the timing or amount of any customer refunds.  At this time, the proceeds are primarily expected to be used by the Yankee Companies to fund remaining fuel storage obligations, and management does not expect any significant amounts to be refunded to Eversource utilities (CL&P, NSTAR Electric, PSNH and WMECO).  The utilities would then ultimately refund any amounts received to utility customers.

D.

FERC ROE Complaints

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

As a result of developments in this matter, the Company recorded reserves across the complaint periods at its electric subsidiaries in the first half of 2015 and recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO.  The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues.  The NETOs and Complainants have filed appeals for the first complaint to the D.C. Circuit Court of Appeals.  A court decision is expected in late 2016.  

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For the second and third complaints, the state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced to an amount lower than 10.57 percent.  The NETOs believe that the Complainants' positions are without merit.  On March 22, 2016, the FERC ALJ issued an initial decision on the second and third FERC ROE 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 Company believes that the range of potential loss 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, the Company concluded there is currently no range of potential loss for that complaint period.  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 outcome of the final FERC order on these 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.

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.

FERC ROE Complaint IV:  On April 29, 2016, a fourth complaint was filed with the FERC by certain municipal utilities claiming 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.  At this time FERC has not taken any action with respect to this complaint; therefore the Company is unable to predict the outcome of this complaint.

E.

PSNH Generation Restructuring

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

On July 1, 2016, the NHPUC approved the Agreement in an order that, among other things, instructs PSNH to begin the process to divest its generation assets.  The NHPUC is in the process of selecting an auction adviser to assist with the divestiture.  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.

If the NHPUC approves the sale of the plants, the Company expects the plants will be sold prior to the end of 2017.  The sales price of the generating assets could be less than the carrying value, but the Company believes that full recovery of PSNH's generation assets is probable through a combination of cash flows during the remaining operating period, sales proceeds upon divestiture, and recovery of stranded costs in future rates.

F.

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"), and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the "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' 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 it has valid defenses to the claims and intends to defend it 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 and NSTAR Electric’s financial position, results of operations, or cash flows.  

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9.

FAIR VALUE OF FINANCIAL INSTRUMENTS

The following methods and assumptions were used to estimate the fair value of each of the following financial instruments:

Preferred Stock and Long-Term Debt:  The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections.  The fair value of long-term debt securities is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields.  The fair values provided in the tables below are classified as Level 2 within the fair value hierarchy.  Carrying amounts and estimated fair values are as follows:

	As of June 30, 2016				As of December 31, 2015
Eversource	Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value
Preferred Stock Not    Subject to Mandatory Redemption	$	155.6	$	157.5	$	155.6	$	157.9
Long-Term Debt		9,614.8		10,512.0		9,034.5		9,425.9

	CL&P				NSTAR Electric				PSNH				WMECO
	Carrying		Fair		Carrying		Fair		Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value		Amount		Value		Amount		Value
As of June 30, 2016:
Preferred Stock Not   Subject to Mandatory Redemption	$	116.2	$	115.0	$	43.0	$	42.5	$	-	$	-	$	-	$	-
Long-Term Debt		2,764.9		3,240.4		2,077.7		2,354.3		1,071.5		1,150.8		566.9		617.3
As of December 31, 2015:
Preferred Stock Not   Subject to Mandatory Redemption	$	116.2	$	114.9	$	43.0	$	43.0	$	-	$	-	$	-	$	-
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

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

Marketable Securities:  Investments in marketable securities are carried at fair value.  For further information, see Note 5, "Marketable Securities," to the financial statements.  

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

10.

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

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

	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
	Qualified		Unrealized						Qualified		Unrealized
	Cash Flow		Gains/(Losses)		Defined				Cash Flow		Gains/(Losses)		Defined
Eversource	Hedging		on Marketable		Benefit				Hedging		on Marketable		Benefit
(Millions of Dollars)	Instruments		Securities		Plans		Total		Instruments		Securities		Plans		Total
Balance as of Beginning of Period	$	(10.3)	$	(1.9)	$	(54.6)	$	(66.8)	$	(12.4)	$	0.7	$	(62.3)	$	(74.0)
OCI Before Reclassifications		-		1.3		(2.6)		(1.3)		-		(1.1)		(0.4)		(1.5)
Amounts Reclassified from AOCI		1.1		-		1.6		2.7		1.0		-		2.5		3.5
Net OCI		1.1		1.3		(1.0)		1.4		1.0		(1.1)		2.1		2.0
Balance as of End of Period	$	(9.2)	$	(0.6)	$	(55.6)	$	(65.4)	$	(11.4)	$	(0.4)	$	(60.2)	$	(72.0)

Eversource's qualified cash flow hedging instruments represent interest rate swap agreements on debt issuances that were settled in prior years.  The settlement amount was recorded in AOCI and is being amortized into Net Income over the term of the underlying debt instrument.  CL&P, PSNH and WMECO continue to amortize interest rate swaps settled in prior years from AOCI into Interest Expense over the remaining life of the associated long-term debt. Such interest rate swaps are not material to their respective financial statements.

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses that arose during the year and were recognized in AOCI.

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

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11.

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

As of both June 30, 2016 and December 31, 2015, there were 16,671,366 Eversource common shares held as treasury shares.  As of June 30, 2016 and December 31, 2015, Eversource common shares outstanding were 317,207,036 and 317,191,249, respectively.  

12.

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for the three months ended June 30, 2016 and 2015, and $3.8 million for the six months ended June 30, 2016 and 2015.  These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income.  Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of June 30, 2016 and December 31, 2015.  Common Shareholders' Equity was fully attributable to the parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest on the Eversource balance sheets.

13.

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 six months ended June 30, 2016 and 2015, there were no antidilutive share awards excluded from the computation.

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

Eversource		For the Three Months Ended				For the Six Months Ended
(Millions of Dollars, except share information)		June 30, 2016		June 30, 2015		June 30, 2016		June 30, 2015
Net Income Attributable to Common Shareholders		$	203.6	$	207.5	$	447.8	$	460.8
Weighted Average Common Shares Outstanding:
	Basic		317,785,495		317,613,166		317,651,319		317,352,004
	Dilutive Effect		691,204		946,402		827,557		1,173,374
	Diluted		318,476,699		318,559,568		318,478,876		318,525,378
Basic and Diluted EPS		$	0.64	$	0.65	$	1.41	$	1.45

14.

SEGMENT INFORMATION

Presentation:  Eversource is organized into 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' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates.  These reportable segments represent substantially all of Eversource's total consolidated revenues.  Revenues from the sale of electricity and natural gas primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer.  The Electric Distribution reportable segment includes the generation activities of PSNH and WMECO.  

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

Cash flows used for investments in plant included in the segment information below are cash capital expenditures that do not include amounts incurred but not paid, cost of removal, AFUDC related to equity funds, and the capitalized portions of pension expense.   

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

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Eversource's segment information is as follows:

Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
For the Three Months Ended June 30, 2016:
Operating Revenues	$	1,303.1	$	180.4	$	302.5	$	211.1	$	(229.9)	$	1,767.2
Depreciation and Amortization		(98.4)		(16.8)		(45.6)		(7.5)		0.5		(167.8)
Other Operating Expenses		(994.4)		(141.1)		(82.5)		(188.1)		230.1		(1,176.0)
Operating Income		210.3		22.5		174.4		15.5		0.7		423.4
Interest Expense		(47.6)		(10.4)		(27.4)		(16.6)		1.5		(100.5)
Other Income, Net		6.3		0.1		5.3		219.0		(222.6)		8.1
Net Income Attributable to Common Shareholders	$	102.8	$	8.0	$	92.5	$	220.7	$	(220.4)	$	203.6
For the Six Months Ended June 30, 2016:
Operating Revenues	$	2,739.2	$	523.0	$	585.8	$	425.3	$	(450.5)	$	3,822.8
Depreciation and Amortization		(226.1)		(32.7)		(90.7)		(14.4)		1.1		(362.8)
Other Operating Expenses		(2,083.3)		(374.5)		(155.5)		(385.4)		450.7		(2,548.0)
Operating Income		429.8		115.8		339.6		25.5		1.3		912.0
Interest Expense		(95.6)		(20.5)		(55.3)		(30.7)		3.4		(198.7)
Other Income/(Loss), Net		6.3		(0.2)		7.9		524.4		(528.4)		10.0
Net Income Attributable to Common Shareholders	$	211.3	$	58.9	$	178.2	$	523.1	$	(523.7)	$	447.8
Cash Flows Used for Investments in Plant	$	362.0	$	105.0	$	349.1	$	53.1	$	-	$	869.2

Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
For the Three Months Ended June 30, 2015:
Operating Revenues	$	1,382.7	$	186.0	$	267.8	$	203.7	$	(223.1)	$	1,817.1
Depreciation and Amortization		(98.5)		(17.7)		(39.7)		(7.1)		0.5		(162.5)
Other Operating Expenses		(1,052.1)		(150.2)		(73.1)		(190.7)		223.5		(1,242.6)
Operating Income		232.1		18.1		155.0		5.9		0.9		412.0
Interest Expense		(45.6)		(9.1)		(26.3)		(12.4)		1.1		(92.3)
Other Income, Net		5.5		0.3		5.1		220.1		(218.1)		12.9
Net Income Attributable to Common Shareholders	$	120.9	$	5.3	$	80.4	$	217.0	$	(216.1)	$	207.5
For the Six Months Ended June 30, 2015:
Operating Revenues	$	3,142.8	$	693.4	$	516.8	$	443.7	$	(466.2)	$	4,330.5
Depreciation and Amortization		(257.6)		(35.9)		(80.1)		(14.3)		1.0		(386.9)
Other Operating Expenses		(2,395.0)		(538.7)		(147.2)		(419.9)		466.7		(3,034.1)
Operating Income		490.2		118.8		289.5		9.5		1.5		909.5
Interest Expense		(93.2)		(18.1)		(53.9)		(24.1)		2.2		(187.1)
Other Income, Net		7.6		0.1		8.1		535.0		(532.2)		18.6
Net Income Attributable to Common Shareholders	$	251.4	$	61.0	$	147.0	$	529.9	$	(528.5)	$	460.8
Cash Flows Used for Investments in Plant	$	319.8	$	67.5	$	328.7	$	24.4	$	-	$	740.4
The following table summarizes Eversource's segmented total assets:
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
As of June 30, 2016	$	17,855.6	$	3,122.5	$	8,376.2	$	13,218.3	$	(11,689.9)	$	30,882.7
As of December 31, 2015		17,981.3		3,104.5		8,019.3		13,256.7		(11,781.5)		30,580.3

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EVERSOURCE ENERGY AND SUBSIDIARIES

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 report on Form 10-Q for the quarter ended March 31, 2016, as well as the Eversource 2015 Form 10-K.  References in this combined Quarterly Report on Form 10-Q to "Eversource," the "Company," "we," "us," and "our" refer to Eversource Energy and its consolidated subsidiaries.  All per share amounts are reported on a diluted basis.  The 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 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 Discussion and Analysis of Financial Condition and Results of Operations.  

The only common equity securities that are publicly traded are common shares of Eversource.  The earnings and EPS of each business discussed below do not represent a direct legal interest in the assets and liabilities of such business but rather represent a direct interest in our assets and liabilities as a whole.  EPS by business is a financial measure not recognized under GAAP that is calculated by dividing the Net Income Attributable to Common Shareholders of each business by the weighted average diluted Eversource common shares outstanding for the period.  The tabular presentations below also include non-GAAP financial measures referencing our second quarter and first half of 2016 and 2015 earnings and EPS excluding certain integration costs.  We use these non-GAAP financial measures to evaluate and to provide details of earnings by business and to more fully compare and explain our second quarter and first half 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, we believe that the non-GAAP presentation is more representative of our financial performance and provides additional and useful information to readers of this report in analyzing historical and future performance by business.  These non-GAAP financial measures should not be considered as an alternative to reported Net Income Attributable to Common Shareholders or EPS determined in accordance with GAAP as an indicator of operating performance.

Reconciliations of the above non-GAAP financial measures to the most directly comparable GAAP measures of consolidated diluted EPS and Net Income Attributable to Common Shareholders are included under "Financial Condition and Business Analysis – Overview – Consolidated" and "Financial Condition and Business Analysis – Overview – Regulated Companies" in 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" within the meaning of the Private Securities Litigation Reform Act of 1995.  You can generally identify our forward-looking statements through the use of words or phrases such as "estimate," "expect," "anticipate," "intend," "plan," "project," "believe," "forecast," "should," "could," and other similar expressions.  Forward-looking statements are based on the current expectations, estimates, assumptions or projections of management and are not guarantees of future performance.  These expectations, estimates, assumptions or projections may vary materially from actual results.  Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, the following important factors that could cause our actual results to differ materially from those contained in our forward-looking statements, including, but not limited to:

·

cyber breaches, acts of war or terrorism, or grid disturbances,

·

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

·

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

·

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

·

fluctuations in weather patterns,

·

changes in laws, regulations or regulatory policy,

·

changes in levels or timing of capital expenditures,

·

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

·

developments in legal or public policy doctrines,

·

technological developments,

·

changes in accounting standards and financial reporting regulations,

·

actions of rating agencies, and

·

other presently unknown or unforeseen factors.  

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

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

32

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 $203.6 million, or $0.64 per share, in the second quarter of 2016, and $447.8 million, or $1.41 per share, in the first half of 2016, compared with $207.5 million, or $0.65 per share, in the second quarter of 2015, and $460.8 million, or $1.45 per share, in the first half of 2015.  

·

Our electric distribution segment, which includes generation, earned $102.8 million, or $0.32 per share, in the second quarter of 2016, and $211.3 million, or $0.66 per share, in the first half of 2016, compared with earnings of $120.9 million, or $0.38 per share, in the second quarter of 2015, and $251.4 million, or $0.80 per share, in the first half of 2015.  

·

Our transmission segment earned $92.5 million, or $0.29 per share, in the second quarter of 2016, and $178.2 million, or $0.56 per share, in the first half of 2016, compared with $80.4 million, or $0.25 per share, in the second quarter of 2015, and $147 million, or $0.46 per share, in the first half of 2015.  

·

Our natural gas distribution segment earned $8.0 million, or $0.03 per share, in the second quarter of 2016, and $58.9 million, or $0.19 per share, in the first half of 2016, compared with $5.3 million, or $0.02 per share, in the second quarter of 2015, and $61 million, or $0.19 per share, in the first half of 2015.  

·

Eversource parent and other companies had earnings of $0.3 million in the second quarter of 2016 and a net loss of $0.6 million in the first half of 2016, compared with earnings of $0.9 million in the second quarter of 2015 and $1.4 million in the first half of 2015.

Liquidity:

·

Cash flows provided by operating activities totaled $978.4 million in the first half of 2016, compared with $865.3 million in the first half of 2015.  Investments in property, plant and equipment totaled $869.2 million in the first half of 2016, compared with $740.4 million in the first half of 2015.  Cash and cash equivalents totaled $38.7 million as of June 30, 2016, compared with $23.9 million as of December 31, 2015.

·

In May 2016, NSTAR Electric repaid at maturity $200 million variable rate debentures using short-term borrowings.  Also in May 2016, NSTAR Electric issued $250 million of 2.70 percent debentures, 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.  The proceeds, net of issuance costs, were used to repay short-term borrowings.   

·

On May 4, 2016, our Board of Trustees approved a common share dividend payment of $0.445 per share, which was paid on June 30, 2016 to shareholders of record as of May 31, 2016.  

Strategic, Legislative, Regulatory, Policy and Other Items:

·

On April 29, 2016, a fourth complaint was filed with the FERC by certain municipal utilities claiming 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.  At this time FERC has not taken any action with respect to this complaint; therefore, we are unable to predict the outcome of this complaint.

·

On June 30, 2016, NSTAR Electric and WMECO filed an application with the DPU seeking approval to develop 35 MW and 27 MW, respectively, of solar generation facilities.  We expect DPU approval of the application by the end of 2016 and expect to complete development of the facilities by the end of 2017.  We estimate our investment in these new facilities will be between approximately $180 million to $200 million if fully approved.

·

On July 1, 2016, the NHPUC approved the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement in an order that, among other things, instructs PSNH to begin the process to divest its generation assets.  

·

On July 31, 2016, the Massachusetts Legislature passed "An Act to Promote Energy Diversity", which requires electric distribution companies to jointly solicit a request for proposal (RFP) and enter into contracts for offshore wind and for hydropower.  The bill is awaiting the governor's signature.  

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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 second quarter and first half of 2016 and 2015.  Also included in the summary for the second quarter and first half 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.

	For the Three Months Ended June 30,								For the Six Months Ended June 30,
(Millions of Dollars, Except	2016				2015				2016				2015
Per Share Amounts)	Amount		Per Share		Amount		Per Share		Amount		Per Share		Amount		Per Share
Net Income Attributable to Common Shareholders (GAAP)	$	203.6	$	0.64	$	207.5	$	0.65	$	447.8	$	1.41	$	460.8	$	1.45
Regulated Companies	$	203.3	$	0.64	$	207.3	$	0.65	$	448.4	$	1.41	$	460.1	$	1.45
Eversource Parent and Other Companies		0.3		-		2.3		0.01		(0.6)		-		6.8		0.02
Non-GAAP Earnings		N/A		N/A		209.6		0.66		N/A		N/A		466.9		1.47
Integration Costs (after-tax)  (1)		N/A		N/A		(2.1)		(0.01)		N/A		N/A		(6.1)		(0.02)
Net Income Attributable to Common Shareholders (GAAP)	$	203.6	$	0.64	$	207.5	$	0.65	$	447.8	$	1.41	$	460.8	$	1.45

⁽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 second quarter and first half of 2016 and 2015 is as follows:  

	For the Three Months Ended June 30,								For the Six Months Ended June 30,
(Millions of Dollars, Except	2016				2015				2016				2015
Per Share Amounts)	Amount		Per Share		Amount		Per Share		Amount		Per Share		Amount		Per Share
Electric Distribution	$	102.8	$	0.32	$	121.6	$	0.38	$	211.3	$	0.66	$	252.1	$	0.80
Electric Transmission		92.5		0.29		80.4		0.25		178.2		0.56		147.0		0.46
Natural Gas Distribution		8.0		0.03		5.3		0.02		58.9		0.19		61.0		0.19
Non-GAAP Earnings		N/A		N/A		207.3		0.65		N/A		N/A		460.1		1.45
Integration Costs (after-tax)		N/A		N/A		(0.7)		-		N/A		N/A		(0.7)		-
Net Income - Regulated Companies	$	203.3	$	0.64	$	206.6	$	0.65	$	448.4	$	1.41	$	459.4	$	1.45

Our electric distribution segment earnings decreased $18.1 million in the second quarter of 2016, as compared to the second quarter of 2015, due primarily to higher operations and maintenance expense, higher depreciation expense and higher property tax expense.  These unfavorable earnings impacts were partially offset by increased CL&P distribution revenues primarily as a result of higher rate base.

Our electric distribution segment earnings decreased $40.1 million in the first half of 2016, as compared to the first half of 2015, 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 the NSTAR Electric and NSTAR Gas Comprehensive Settlement Agreement recorded in the first quarter of 2015 ($13 million), lower retail sales volumes at NSTAR Electric and PSNH as a result of the 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 expense.  These unfavorable earnings impacts were partially offset by increased CL&P distribution revenues primarily as a result of higher rate base.  

Our electric transmission segment earnings increased $12.1 million in the second quarter of 2016, as compared to the second quarter of 2015, due primarily to a higher transmission rate base as a result of increased investments in our transmission infrastructure.

Our electric transmission segment earnings increased $31.2 million in the first half of 2016, as compared to the first half of 2015, due primarily to the absence in 2016 of reserve charges of $12.4 million recorded in 2015 associated with the FERC ROE complaint proceedings and a higher transmission rate base as a result of increased investments in our transmission infrastructure.

Our natural gas distribution segment earnings increased $2.7 million in the second quarter of 2016, as compared to the second quarter of 2015, due primarily to the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016 and higher non-decoupled firm natural gas sales volumes driven by the cooler than normal weather in the spring of 2016, as compared to the same period in 2015.  These favorable earnings impacts were partially offset by higher operations and maintenance expense and higher property tax expense.

Our natural gas distribution segment earnings decreased $2.1 million in the first half of 2016, as compared to the first half of 2015, due primarily to lower non-decoupled firm natural gas sales volumes driven by the warmer than normal weather in the first quarter of 2016, as compared to the much colder than normal temperatures in the first quarter of 2015.  Partially offsetting this unfavorable earnings impact was a decrease in operations and maintenance expense and the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016.

34

Eversource Parent and Other Companies:  Eversource parent and other companies had earnings of $0.3 million in the second quarter of 2016 and a net loss of $0.6 million in the first half of 2016, compared with earnings of $0.9 million and $1.4 million in the second quarter and first half of 2015, respectively.  The earnings decrease in the first half of 2016 was due primarily to a higher effective tax rate and higher interest expense, partially offset by the absence in 2016 of integration costs.

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

Fluctuations in retail electric sales volumes at NSTAR Electric and PSNH impact earnings ("Traditional" in the table below).  For CL&P and WMECO, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission approved distribution revenue decoupling mechanisms ("Decoupled" in the table below).  These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized.  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.

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

	For the Three Months Ended June 30, 2016 Compared to 2015			For the Six Months Ended June 30, 2016 Compared to 2015
	Sales Volumes (GWh)		Percentage	Sales Volumes (GWh)		Percentage
Electric	2016	2015	Increase/(Decrease)	2016	2015	Decrease
Traditional:
Residential	2,092	2,127	(1.6)%	4,497	4,874	(7.7)%
Commercial	3,861	3,892	(0.8)%	7,852	8,032	(2.2)%
Industrial	652	652	(0.1)%	1,252	1,266	(1.2)%
Total – Traditional	6,605	6,671	(1.0)%	13,601	14,172	(4.0)%
Decoupled:
Residential	2,410	2,393	0.7 %	5,353	5,863	(8.7)%
Commercial	2,658	2,702	(1.6)%	5,275	5,494	(4.0)%
Industrial	730	753	(3.0)%	1,394	1,439	(3.1)%
Total – Decoupled	5,798	5,848	(0.8)%	12,022	12,796	(6.0)%
Total Sales Volumes	12,403	12,519	(0.9)%	25,623	26,968	(5.0)%

	For the Three Months Ended June 30, 2016 Compared to 2015			For the Six Months Ended June 30, 2016 Compared to 2015
	Sales Volumes (Mcf)		Percentage	Sales Volumes (Mcf)		Percentage
Firm Natural Gas	2016	2015	Increase/(Decrease)	2016	2015	(Decrease)/Increase
Traditional:
Residential	2,511	2,081	20.7 %	9,153	11,068	(17.3)%
Commercial	3,538	3,299	7.2 %	11,514	13,268	(13.2)%
Industrial	2,266	2,443	(7.2)%	5,633	6,570	(14.3)%
Total – Traditional	8,315	7,823	6.3 %	26,300	30,906	(14.9)%
Decoupled:
Residential	3,231	3,079	4.9 %	12,540	15,547	(19.3)%
Commercial	3,884	3,583	8.4 %	12,872	14,937	(13.8)%
Industrial	1,319	1,217	8.3 %	3,173	3,693	(14.1)%
Total – Decoupled	8,434	7,879	7.0 %	28,585	34,177	(16.4)%
Special Contracts (1)	1,087	1,079	0.7 %	2,299	2,270	1.3 %
Total – Decoupled and   Special Contracts	9,521	8,958	6.3 %	30,884	36,447	(15.3)%
Total Sales Volumes	17,836	16,781	6.3 %	57,184	67,353	(15.1)%

⁽¹⁾

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

For the second quarter of 2016, retail electric sales volumes at our electric utilities with a traditional rate structure (NSTAR Electric and PSNH) remained relatively unchanged, as compared to the second quarter of 2015.  For the first half of 2016, retail electric sales volumes at our electric utilities with a traditional rate structure were lower, as compared to the first half of 2015, due primarily to the impact of warmer than normal 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.  First half 2016 heating degree days were 19.2 percent lower in the Boston metropolitan area and 18.6 percent lower in New Hampshire, as compared to the same period in 2015.  

35

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 $13.8 million and $26.8 million in the second quarter and first half of 2016, respectively, compared to $15.2 million and $27.7 million in the second quarter and first half of 2015, respectively.

Our firm natural gas sales volumes are subject to many of the same influences as our retail electric sales volumes.  In addition, they have benefited from customer growth in both of our natural gas distribution companies.  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.  Natural gas distribution revenues are decoupled from their customer sales volumes, where applicable, which breaks the relationship between sales volumes and revenues recognized.  In the second quarter of 2016, our consolidated firm natural gas sales volumes were higher, as compared to the second quarter of 2015, due primarily to cooler temperatures as well as customer growth, partially offset by customer conservation efforts resulting from company-sponsored energy efficiency programs.  Consolidated firm natural gas sales volumes were much lower in the first half of 2016, as compared to the first half of 2015.  The first half 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.  First half 2016 heating degree days were 17.4 percent lower in Connecticut, as compared to the same period in 2015.

Liquidity

Consolidated:  Cash and cash equivalents totaled $38.7 million as of June 30, 2016, compared with $23.9 million as of December 31, 2015.

Long-Term Debt Issuances and Repayments:  In May 2016, NSTAR Electric repaid at maturity $200 million variable rate debentures using short-term borrowings.  Also in May 2016, NSTAR Electric issued $250 million of 2.70 percent debentures, 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.  The proceeds, net of issuance costs, were used to repay short-term borrowings.  

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 June 30, 2016 and December 31, 2015, Eversource parent had $438 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $1.0 billion and $351.5 million of available borrowing capacity as of June 30, 2016 and December 31, 2015, respectively.  The weighted-average interest rate on these borrowings as of June 30, 2016 and December 31, 2015 was 0.66 percent and 0.72 percent, respectively.  As of June 30, 2016, there were intercompany loans from Eversource parent of $93 million to CL&P, $120.9 million to PSNH, and $53.7 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 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, which terminates on September 4, 2020.  The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program.  

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 June 30, 2016 and December 31, 2015, NSTAR Electric had $329 million and $62.5 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $121 million and $387.5 million of available borrowing capacity as of June 30, 2016 and December 31, 2015, respectively.  The weighted-average interest rate on these borrowings as of June 30, 2016 and December 31, 2015 was 0.44 percent and 0.40 percent, respectively.  NSTAR Electric is party to a five-year $450 million revolving credit facility, which terminates on September 4, 2020.  The revolving credit facility serves to backstop NSTAR Electric's $450 million commercial paper program.   

Cash Flows:  Cash flows provided by operating activities totaled $978.4 million in the first half of 2016, compared with $865.3 million in the first half of 2015.  The increase in operating cash flows was due primarily to timing of collections related to accounts receivable and the timing of payments related to accounts payable.  Also contributing to the increase was an increase in regulatory recoveries, primarily at NSTAR Electric, due to collections from customers in excess of purchased power costs, as well as an increase of $67.8 million in income tax refunds received in the first half of 2016, as compared to the first half of 2015.  Partially offsetting these favorable cash flow impacts were an increase of $34.9 million in Pension and PBOP Plan cash contributions in the first half of 2016, as compared to the same period in 2015, and an increase in fuel inventory balances at PSNH.

Credit Ratings:  On May 26, 2016, Moody’s upgraded WMECO’s corporate credit rating and senior unsecured debt credit rating by one level and changed the outlook from positive to stable.  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.  

36

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 May 4, 2016, our Board of Trustees approved a common share dividend payment of $0.445 per share, which was paid on June 30, 2016 to shareholders of record as of May 31, 2016.  In the first half of 2016, we paid cash dividends on common shares of $282.3 million, compared with $264.9 million in the first half of 2015.

In the first half of 2016, CL&P, NSTAR Electric, PSNH, and WMECO paid $99.8 million, $278.3 million, $38.8 million, and $19 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 half of 2016, investments for Eversource, CL&P, NSTAR Electric, PSNH, and WMECO were $869.2 million, $288.6 million, $199.8 million, $138.7 million, and $71.5 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 $905.0 million in the first half of 2016, compared to $770.9 million in the first half of 2015.  These amounts included $58.0 million and $28.5 million in the first half of 2016 and 2015, 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 Corp and National Grid.  Access Northeast will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes and will include two new LNG storage tanks and liquefaction and vaporization facilities in Acushnet, Massachusetts that will be connected to the Algonquin natural gas pipeline.  The Project is expected to be capable of delivering approximately 900 million cubic feet of additional natural gas per day to New England on peak demand days.  Eversource and Spectra Energy Corp each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid.  The total projected cost for both the pipeline and the LNG storage is expected to be approximately $3 billion with anticipated in-service dates commencing in November 2018.  The Project is subject to FERC and other federal and state regulatory approvals.  On November 17, 2015, the FERC accepted the Project's request to initiate the pre-filing review process.  Upon completion of the pre-filing review, a certificate application will be filed with the FERC.  For further information on the natural gas pipeline capacity RFP process and Access Northeast’s participation, see "Regulatory Developments and Rate Matters – General – New England Natural Gas Pipeline Capacity" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

Electric Transmission Business:  Our consolidated electric transmission business capital expenditures increased by $37.2 million in the first half of 2016, as compared to the first half of 2015.  A summary of electric transmission capital expenditures by company is as follows:  

	For the Six Months Ended June 30,
(Millions of Dollars)	2016		2015
CL&P	$	140.9	$	99.1
NSTAR Electric		107.6		86.8
PSNH		50.4		70.2
WMECO		46.1		49.2
NPT		16.0		18.5
Total Electric Transmission Segment	$	361.0	$	323.8

37

GHCC:  The Greater Hartford Central Connecticut (GHCC) solutions, which have been approved by ISO-NE, are comprised of 27 projects and are expected to cost approximately $350 million and be placed in service from 2016 through 2018.  Six projects have been placed in service and during the remainder of 2016, 12 additional projects are expected to be in active construction.  All GHCC projects are expected to be completed by late 2018.  As of June 30, 2016, CL&P had capitalized $79.9 million in costs associated with GHCC.  

Northern Pass:  Northern Pass is Eversource's planned HVDC transmission line from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire.  Northern Pass will interconnect at the Québec-New Hampshire border with a planned HQ HVDC transmission line.  On July 21, 2015, the DOE issued the draft Environmental Impact Statement (EIS) for Northern Pass representing a key milestone in the permitting process.  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 quarter of 2017.  On August 18, 2015, NPT announced the Forward NH Plan, including a commitment to allocate $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 application to operate as a public utility once the project is fully permitted.  The settlement agreement is subject to NHPUC approval.  Additionally, on June 28, 2016, as part of the Forward NH Plan, PSNH filed a power purchase agreement (PPA) with the NHPUC.  The PPA, combined with the Forward New Hampshire Plan, is expected to deliver over $1 billion of energy cost savings and other benefits over the contract term to New Hampshire customers.  The Forward NH Plan and the PPA are both commitments that are contingent upon the Northern Pass transmission line going into commercial operation.  

The New Hampshire Site Evaluation Committee (NH SEC) is currently in process of formal siting.  The NH SEC is expected to issue an order on NPT no later than September 2017 and the project is expected to be operational by the end of 2019.  On January 28, 2016, NPT bid into the three-state Clean Energy RFP process.  For further information on the RFP process, see "Regulatory Developments and Rate Matters – General – Clean Energy RFP" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.  

Greater Boston Reliability Solutions:In February 2015, ISO-NE selected Eversource's and National Grid's proposed Greater Boston and New Hampshire Solution (Solution) to satisfy the requirements identified in the Greater Boston study.  The Solution consists of a portfolio of some 40 electric transmission upgrades straddling southern New Hampshire and northern Massachusetts in the Merrimack Valley and continuing into the greater Boston metropolitan area, of which 31 are in Eversource’s service territory. We are currently pursuing the necessary regulatory and siting application approvals in Massachusetts and New Hampshire.  Construction has begun on several of the smaller projects not requiring siting approval, and construction on an additional project approved by the DPU is expected to begin in the third quarter of 2016.  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 million, of which approximately $78.2 million has been capitalized through June 30, 2016.

Seacoast Reliability Project:  On April 12, 2016, PSNH filed a siting application with the NH SEC for the Seacoast Reliability Project, a 13-mile 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.  This project is expected to be completed by the end of 2018.  We estimate our investment in this project will be approximately $77 million, of which approximately $9.5 million has been capitalized through June 30, 2016.

38

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

	For the Six Months Ended June 30,
(Millions of Dollars)	2016		2015
CL&P:
Basic Business	$	84.1	$	62.9
Aging Infrastructure		62.3		75.7
Load Growth		16.9		18.5
Total CL&P		163.3		157.1
NSTAR Electric:
Basic Business		54.6		54.0
Aging Infrastructure		35.6		34.7
Load Growth		26.2		14.0
Total NSTAR Electric		116.4		102.7
PSNH:
Basic Business		32.2		25.3
Aging Infrastructure		39.4		21.2
Load Growth		5.4		10.9
Total PSNH		77.0		57.4
WMECO:
Basic Business		7.8		7.3
Aging Infrastructure		9.8		9.2
Load Growth		(0.4)		3.7
Total WMECO		17.2		20.2
Total - Electric Distribution (excluding Generation)		373.9		337.4
PSNH Generation		2.7		8.7
Natural Gas:
Basic Business		35.2		24.0
Aging Infrastructure		59.9		34.4
Load Growth		14.3		14.1
Total – Natural Gas Distribution		109.4		72.5
Total Electric and Natural Gas Distribution Segment	$	486.0	$	418.6

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.

FERC Regulatory Matters

FERC ROE Complaints I, II and III:  Three separate complaints have been filed at FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively the "Complainants").  The Complainants challenged the NETOs' base ROE of 11.14 percent and sought to reduce it both for the three separate 15-month complaint periods and prospectively.  In 2014, the FERC ordered a 10.57 percent base ROE for the first complaint period and prospectively from October 16, 2014, and that a utility's total or maximum ROE shall not exceed the top of the new zone of reasonableness, which was set at 11.74 percent.  We have refunded all amounts associated with the first complaint period.  

As a result of developments in this matter, the Company recorded reserves across the complaint periods at its electric subsidiaries in the first half of 2015 and recognized an after-tax charge to earnings (excluding interest) of $12.4 million, of which $7.9 million was recorded at CL&P, $1.4 million at NSTAR Electric, $0.6 million at PSNH, and $2.5 million at WMECO.

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 determine both the base ROE and the maximum ROE for transmission incentive projects for the two complaint periods.  The final FERC order, when issued, will also establish the prospective base ROE and maximum ROE for transmission incentive projects.

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We have not recorded any additional reserves to reflect the ROEs recommended in 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 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 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 our existing reserves.

FERC ROE Complaint IV:  On April 29, 2016, a fourth complaint was filed with the FERC by certain municipal utilities claiming 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.  At this time FERC has not taken any action with respect to this complaint; therefore, we are unable to predict the outcome of this complaint.

Merger Cost Filing:  On February 26, 2016, Eversource Energy Service Company filed an application with the FERC to recover through transmission rates approximately $37.4 million of costs associated with the merger of Northeast Utilities and NSTAR.  On May 3, 2016, FERC issued an order allowing the Company to recover these transmission related merger costs over a three year period, beginning June 1, 2016, subject to refund, and setting the application for settlement and hearing.  

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, selection of which was expected to be completed in July 2016.  Due to the volume of the proposals received and the complexity of the related analysis, the Evaluation Committee has delayed selection of the winning contracts.  At this time it is unknown when the selection of the contracts will be completed by the Evaluation Committee.  Final results of the RFP will be announced when the EDCs executed contracts are submitted for approval to their respective state regulatory commissions.   

New England Natural Gas Pipeline Capacity:  NSTAR Electric, WMECO and National Grid have filed with the DPU seeking approval of contracts, including contracts with Access Northeast, for natural gas pipeline capacity and storage.  PSNH has filed with the NHPUC, seeking approval of its contract with Access Northeast for natural gas pipeline capacity and storage.On June 2, 2016, the DEEP issued an RFP for natural gas pipeline capacity and storage.  Proposals were received on June 29, 2016.  Contracts with proposals selected by DEEP are scheduled to be submitted to PURA no later than October 31, 2016 with approval expected no later than January 31, 2017.  On June 30, 2016, National Grid filed with the Rhode Island Public Utilities Commission seeking approval of its contract with Access Northeast for natural gas pipeline capacity and storage.  On July 19, 2016, the Maine PUC voted to move forward with an Access Northeast contract for natural gas pipeline capacity, contingent upon the participation by electric distribution companies in other New England states.  For further information on Access Northeast, see "Business Development and Capital Expenditures –– Natural Gas Transmission Business" 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 half of 2016, 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 Form 10-K.

Massachusetts:

Solar Generation:  On June 30, 2016, NSTAR Electric and WMECO filed an application with the DPU seeking approval to develop 35 MW and 27 MW, respectively, of solar generation facilities, in addition to WMECO’s existing 8 MW of solar generation facilities.  The DPU is expected to issue a decision on the application by the end of 2016, and we expect development of the facilities to be completed by the end of 2017.  We estimate our investment in these new facilities will be between approximately $180 million to $200 million if fully approved.  

July 2016 Storm Filing:  On July 6, 2016, NSTAR Electric filed with the DPU a final accounting of incremental, storm-related preparation and response costs totaling approximately $109 million for eight storms that occurred between 2012 through 2015.  In the filing, NSTAR Electric requested that the DPU investigate the storm-related costs and render a determination as to the final storm-related costs eligible for recovery.  Recovery of these costs would occur in accordance with a DPU decision in NSTAR Electric's next distribution rate case.

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New Hampshire:

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

On July 1, 2016, the NHPUC approved the Agreement in an order that, among other things, instructs PSNH to begin the process to divest its generation assets.  The NHPUC is in the process of selecting an auction adviser to assist with the divestiture.  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 generation assets is probable through a combination of cash flows during the remaining operating period, sales proceeds upon divestiture, and recovery of stranded costs in future rates.  

Legislative and Policy Matters

Massachusetts

On April 11, 2016, "An Act Relative to Solar Energy" became law, which raises the solar net metering cap levels by three percent for both private and public projects.  Utilities may file proposals with the DPU to ensure that all distribution customers contribute to the fixed costs of maintaining distribution systems.  For further information, see "Regulatory Developments and Rate Matters – Massachusetts – Solar Generation" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.  

On July 31, 2016,in conjunction with efforts to shape comprehensive energy legislation, the Massachusetts Legislature passed "An Act to Promote Energy Diversity", which requires electric distribution companies to jointly solicit RFPs and enter into 15- to 20-year contracts for 1,600 MW of offshore wind and 1,200 MW of hydropower or other renewable sources, such as land-based wind or solar.  The bill is awaiting the governor's signature.  

New Hampshire

On May 2, 2016, "An Act Relative to Net Metering" became law, which raises the cap on net energy metering tariffs available to eligible customer generators from 50 MW to 100 MW and requires the NHPUC to initiate a proceeding to develop alternative net energy metering tariffs.  We do not believe that this law will have a material financial impact on the Company.  

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 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 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 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 EDGAR website (http://www.sec.gov/edgar/searchedgar/companysearch.html), at which site Eversource's, CL&P's, NSTAR Electric's, PSNH's and 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 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.

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RESULTS OF OPERATIONS – EVERSOURCE ENERGY AND SUBSIDIARIES

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

			For the Three Months Ended June 30,								For the Six Months Ended June 30,
							Increase/								Increase/
(Millions of Dollars)			2016		2015		(Decrease)		Percent		2016		2015		(Decrease)		Percent
Operating Revenues			$	1,767.2	$	1,817.1	$	(49.9)	(2.7)	%	$	3,822.8	$	4,330.5	$	(507.7)	(11.7)	%
Operating Expenses:
	Purchased Power, Fuel and Transmission			581.3		685.1		(103.8)	(15.2)			1,336.1		1,847.2		(511.1)	(27.7)
	Operations and Maintenance			320.7		316.7		4.0	1.3			640.9		650.0		(9.1)	(1.4)
	Depreciation			176.5		163.7		12.8	7.8			350.5		327.5		23.0	7.0
	Amortization of Regulatory (Liabilities)/Assets, Net			(8.7)		(1.2)		(7.5)	(a)			12.3		59.4		(47.1)	(79.3)
	Energy Efficiency Programs			119.7		101.9		17.8	17.5			256.8		248.5		8.3	3.3
	Taxes Other Than Income Taxes			154.3		138.9		15.4	11.1			314.2		288.4		25.8	8.9
		Total Operating Expenses		1,343.8		1,405.1		(61.3)	(4.4)			2,910.8		3,421.0		(510.2)	(14.9)
Operating Income				423.4		412.0		11.4	2.8			912.0		909.5		2.5	0.3
Interest Expense				100.5		92.3		8.2	8.9			198.7		187.1		11.6	6.2
Other Income, Net				8.1		13.0		(4.9)	(37.7)			10.0		18.7		(8.7)	(46.5)
Income Before Income Tax Expense				331.0		332.7		(1.7)	(0.5)			723.3		741.1		(17.8)	(2.4)
Income Tax Expense				125.5		123.3		2.2	1.8			271.7		276.5		(4.8)	(1.7)
Net Income				205.5		209.4		(3.9)	(1.9)			451.6		464.6		(13.0)	(2.8)
Net Income Attributable to Noncontrolling Interests				1.9		1.9		-	-			3.8		3.8		-	-
Net Income Attributable to Common Shareholders			$	203.6	$	207.5	$	(3.9)	(1.9)	%	$	447.8	$	460.8	$	(13.0)	(2.8)	%
Operating Revenues
			For the Three Months Ended June 30,								For the Six Months Ended June 30,
							Increase/									Increase/
(Millions of Dollars)			2016		2015		(Decrease)		Percent		2016		2015		(Decrease)		Percent
Electric Distribution			$	1,303.1	$	1,382.7	$	(79.6)	(5.8)	%	$	2,739.2	$	3,142.8	$	(403.6)	(12.8)	%
Natural Gas Distribution				180.4		186.0		(5.6)	(3.0)			523.0		693.4		(170.4)	(24.6)
Electric Transmission				302.5		267.8		34.7	13.0			585.8		516.8		69.0	13.4
Other and Eliminations				(18.8)		(19.4)		0.6	(3.1)			(25.2)		(22.5)		(2.7)	12.0
Total Operating Revenues			$	1,767.2	$	1,817.1	$	(49.9)	(2.7)	%	$	3,822.8	$	4,330.5	$	(507.7)	(11.7)	%
(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 June 30,								For the Six Months Ended June 30,
							Increase/
			2016		2015		(Decrease)		Percent		2016		2015		Decrease		Percent
Electric
	Traditional			6,605		6,671		(66)	(1.0)	%		13,601		14,172		(571)	(4.0)	%
	Decoupled			5,798		5,848		(50)	(0.8)			12,022		12,796		(774)	(6.0)
Total Electric				12,403		12,519		(116)	(0.9)			25,623		26,968		(1,345)	(5.0)
Firm Natural Gas
	Traditional			8,315		7,823		492	6.3			26,300		30,906		(4,606)	(14.9)
	Decoupled and Special Contracts			9,521		8,958		563	6.3			30,884		36,447		(5,563)	(15.3)
Total Firm Natural Gas				17,836		16,781		1,055	6.3	%		57,184		67,353		(10,169)	(15.1)	%

Three Months Ended:

Operating Revenues, which primarily consist of base electric and natural gas distribution revenues and tracked revenues further described below, decreased by $49.9 million for the three months ended June 30, 2016, as compared to the same period in 2015.  

Base electric and natural gas distribution revenues:  Base electric distribution segment revenues increased $4.7 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 ($4 million) and   the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, recorded in the second quarter of 2015 at CL&P ($1.1 million).  Partially offsetting this increase was the impact of increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs experienced in the second quarter of 2016, as compared to the second quarter of 2015, resulting in a 1 percent decrease in traditional retail sales volumes at NSTAR Electric and PSNH ($0.4 million).

Firm natural gas base distribution segment revenues increased $7.1 million due primarily to a 6.3 percent increase in traditional firm natural gas sales volumes and the impact of the NSTAR Gas base distribution rate increase effective January 1, 2016.  

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

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Tracked distribution revenues: Tracked revenues consist of certain costs that are recovered from customers in rates through regulatory commission-approved cost tracking mechanisms and therefore have no impact on earnings.  Costs recovered through cost tracking mechanisms include energy supply procurement costs and other energy-related costs for our electric and natural gas customers, retail transmission charges, energy efficiency program costs, and restructuring and stranded cost recovery revenues.  Tracked electric distribution segment revenues decreased as a result of decreases in energy supply costs ($142.7 million), driven by decreased average retail rates and lower sales volumes, partially offset by an increase in retail electric transmission charges ($23 million), an increase in energy efficiency program revenues ($20.8 million), an increase in federally mandated congestion charges ($18.5 million), and an increase in net metering for distributed generation revenues ($7.8 million).  In addition, CL&P's system benefits charge revenues increased by $5.2 million, which impacted earnings as a result of a higher rate base.

The second quarter 2016 tracked natural gas distribution segment revenues decreased as a result of decreases in natural gas supply costs ($7.2 million) and a decrease in energy efficiency program revenues ($5.3 million).

Electric transmission revenues:  The electric transmission segment revenues increased by $34.7 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Six Months Ended:

Operating Revenues decreased by $507.7 million for the six months ended June 30, 2016, as compared to the same period in 2015.  

Base electric and natural gas distribution revenues:  Base electric distribution segment revenues decreased $2.2 million due primarily to weather impacts.  The impact 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, as well as increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, were the primary drivers of a 4 percent decrease in traditional retail sales volumes at NSTAR Electric and PSNH during the first half of 2016 ($15.1 million).  The decrease in base electric distribution revenues was partially offset by a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates at CL&P ($10.7 million) and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, recorded in the first half of 2015 at CL&P ($2.2 million).

Also contributing to the decrease in operating revenues in the first half 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 $9.7 million due primarily to a 14.9 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 ($510 million), driven by decreased average retail rates and lower sales volumes, partially offset by an increase in retail electric transmission charges ($37.8 million), an increase in federally mandated congestion charges ($29.9 million), an increase in energy efficiency program revenues ($27.8 million), and an increase in net metering for distributed generation revenues ($15 million).  In addition, CL&P's system benefits charge revenues increased by $9.3 million, which impacted earnings as a result of a higher rate base.  Tracked natural gas distribution segment revenues decreased as a result of decreases in natural gas supply costs ($137.7 million) driven by decreased average rates and lower sales volumes, and a decrease in energy efficiency program revenues ($23 million).

Electric transmission revenues:  The electric transmission segment revenues increased by $69 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 six months ended June 30, 2016, as compared to the same periods in 2015, due primarily to the following:

	Three Months Ended		Six Months Ended
(Millions of Dollars)	(Decrease)/Increase		(Decrease)/Increase
Electric Distribution	$	(144.3)	$	(452.8)
Natural Gas Distribution		(8.0)		(135.9)
Transmission		48.5		77.6
Total Purchased Power, Fuel and Transmission	$	(103.8)	$	(511.1)

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

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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 increased for the three months ended June 30, 2016 and decreased for the six months ended June 30, 2016, as compared to the same periods in 2015, due primarily to the following:

	Three Months Ended		Six Months Ended
(Millions of Dollars)	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		3.3		6.3
Vegetation management costs		1.3		4.6
Absence of 2015 contribution to create clean energy fund in connection with the generation      divestiture agreement at PSNH		(5.0)		(5.0)
Employee-related expenses, including labor and benefits		11.6		(5.3)
Other operations and maintenance		(0.3)		1.1
Total Base Electric Distribution		10.9		25.9
Total Base Natural Gas Distribution:
Employee-related expenses, including labor and benefits		(1.6)		(11.8)
Other operations and maintenance		2.8		2.9
Total Base Natural Gas Distribution		1.2		(8.9)
Total Tracked costs (Electric Distribution, Electric Transmission and Natural Gas Distribution)		3.6		4.3
Other and eliminations:
Integration costs		(3.5)		(10.5)
Absence of Eversource's unregulated electrical contracting business due to sale in April 2015, net		-		(10.6)
Eversource Parent and Other Companies		(8.2)		(9.3)
Total Operations and Maintenance	$	4.0	$	(9.1)

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

Amortization of Regulatory (Liabilities)/Assets, Net expense (the costs of which are tracked) include 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 (Liabilities)/Assets, Net, decreased for the three and six months ended June 30, 2016, as compared to the same periods in 2015, due primarily to the deferral of energy supply and energy-related costs which can fluctuate from period to period based on the timing of costs incurred and the related rate changes to recover these costs.  Energy supply and energy-related costs at CL&P, NSTAR Electric, PSNH and WMECO, which are the primary drivers in amortization, are recovered from customers in rates and have no impact on earnings.  

Partially offsetting the decrease in Amortization of Regulatory (Liabilities)/Assets, Net, for the six months ended June 30, 2016 was 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 six months ended June 30, 2016, as compared to the same periods in 2015, due primarily to deferral adjustments at CL&P, NSTAR Electric and the natural gas businesses, which reflect the actual costs of energy efficiency programs compared to the estimated amounts billed to customers, and an increase in energy efficiency costs incurred in accordance with the three-year program guidelines established by the DPU.  The deferrals adjust expense to match the energy efficiency programs revenue.  The costs for various state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates and have no impact on earnings.

Taxes Other Than Income Taxes expense increased for the three and six months ended June 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).

Interest Expense increased for the three months ended June 30, 2016, as compared to the same period in 2015, due primarily to higher interest on long-term debt ($9.6 million) as a result of new debt issuances, partially offset by lower interest on regulatory deferral mechanisms ($1.8 million).

Interest Expense increased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to higher interest on long-term debt ($16.2 million) as a result of new debt issuances, partially offset by lower interest on regulatory deferral mechanisms ($5.1million).

Other Income, Net decreased for the three months ended June 30, 2016, as compared to the same period in 2015, due primarily to a decrease in net gains related to the deferred compensation plans ($6.6 million), partially offset by higher AFUDC related to equity funds ($2.3 million).

Other Income, Net decreased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to a decrease in net gains related to the deferred compensation plans ($10.2 million), partially offset by higher AFUDC related to equity funds ($2.9 million).

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Income Tax Expense increased for the three months ended June 30, 2016, as compared to the same period in 2015, due primarily to higher state taxes ($1.1 million) and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($1.5 million), partially offset by lower pre-tax earnings ($0.6 million).

Income Tax Expense decreased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to lower pre-tax earnings ($5.3 million) and the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($2.7 million), partially offset by higher state taxes ($1.8 million) and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($1.5 million).

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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 six months ended June 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  

			For the Three Months Ended June 30,								For the Six Months Ended June 30,
							Increase/								Increase/
(Millions of Dollars)			2016		2015		(Decrease)		Percent		2016		2015		(Decrease)		Percent
Operating Revenues			$	679.8	$	666.6	$	13.2	2.0	%	$	1,415.1	$	1,471.5	$	(56.4)	(3.8)	%
Operating Expenses:
	Purchased Power and Transmission			234.5		253.2		(18.7)	(7.4)			507.1		586.8		(79.7)	(13.6)
	Operations and Maintenance			122.5		118.7		3.8	3.2			233.4		236.0		(2.6)	(1.1)
	Depreciation			57.5		52.2		5.3	10.2			114.5		105.1		9.4	8.9
	Amortization of Regulatory (Liabilities)/Assets, Net			(2.9)		(7.5)		4.6	(61.3)			6.9		40.8		(33.9)	(83.1)
	Energy Efficiency Programs			35.5		33.9		1.6	4.7			73.6		76.8		(3.2)	(4.2)
	Taxes Other Than Income Taxes			70.6		62.1		8.5	13.7			146.0		130.2		15.8	12.1
		Total Operating Expenses		517.7		512.6		5.1	1.0			1,081.5		1,175.7		(94.2)	(8.0)
Operating Income				162.1		154.0		8.1	5.3			333.6		295.8		37.8	12.8
Interest Expense				36.0		36.1		(0.1)	(0.3)			72.5		72.7		(0.2)	(0.3)
Other Income, Net				6.3		4.0		2.3	57.5			7.2		6.2		1.0	16.1
Income Before Income Tax Expense				132.4		121.9		10.5	8.6			268.3		229.3		39.0	17.0
Income Tax Expense				49.5		43.1		6.4	14.8			98.4		81.3		17.1	21.0
Net Income			$	82.9	$	78.8	$	4.1	5.2	%	$	169.9	$	148.0	$	21.9	14.8	%
Operating Revenues
CL&P's retail sales volumes were as follows:
			For the Three Months Ended June 30,								For the Six Months Ended June 30,
			2016		2015		Decrease		Percent		2016		2015		Decrease		Percent
Retail Sales Volumes in GWh				4,966		5,027		(61)	(1.2)	%		10,316		11,021		(705)	(6.4)	%

Three Months Ended:

CL&P's Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, increased by $13.2 million for the three months ended June 30, 2016, as compared to the same period in 2015.

Base distribution revenues increased by $5.1 million due to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates ($4 million) and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, recorded in the second quarter of 2015 ($1.1 million).  

Fluctuations in CL&P's sales volumes do not impact the level of base distribution revenue realized or earnings due to the PURA approved revenue decoupling mechanism.  CL&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.  Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs ($39.2 million) driven by decreased average retail rates.  Partially offsetting this decrease was an increase in federally mandated congestion charges ($18.5 million) and an increase in competitive transition assessment charges ($7.9 million).  In addition, system benefits charge revenues increased by $5.2 million, which impacted earnings as a result of a higher rate base.

Transmission revenues increased by $20.8 million due primarily to higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Six Months Ended:

CL&P's Operating Revenues decreased by $56.4 million for the six months ended June 30, 2016, as compared to the same period in 2015.

Base distribution revenues increased by $12.9 million due to a higher rate base resulting from the 2015 PURA ADIT settlement agreement that is being collected from customers in distribution rates ($10.7 million) and the absence of an authorized ROE reduction, as stipulated in the PURA 2014 rate case decision, recorded in the first half of 2015 ($2.2 million).  

Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs ($160 million) driven by decreased average retail rates and lower sales volumes.  Partially offsetting this decrease was an increase in retail transmission charges ($17.8 million), an increase in federally mandated congestion charges ($29.9 million) and an increase in competitive transition assessment charges ($14.3 million).  In addition, system benefits charge revenues increased by $9.3 million, which impacted earnings as a result of a higher rate base.

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Transmission revenues increased by $36.2 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 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 six months ended June 30 2016, as compared to the same periods in 2015, due primarily to the following:

	Three Months Ended		Six Months Ended
(Millions of Dollars)	(Decrease)/Increase		(Decrease)/Increase
Purchased Power Costs	$	(38.6)	$	(112.7)
Transmission Costs		19.9		33.0
Total Purchased Power and Transmission	$	(18.7)	$	(79.7)

Included in purchased power costs are the costs associated with CL&P's generation services charge (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 was due primarily to a decrease in the prices of standard offer supply for both the three and six months ended June 30, 2016, compared to the same periods in June 30, 2015, and lower sales volumes for the six months ended June 30, 2016, compared to the same period in June 30, 2015.  The increase in transmission costs was primarily the result of an increase in the RNS costs billed by ISO-NE.   

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 June 30, 2016, as compared to the same period in 2015, driven by a $3.8 million increase in non-tracked costs, which was primarily attributable to higher storm restoration costs and higher employee-related expenses, partially offset by reimbursement of legal fees in the second quarter of 2016 and the absence in 2016 of integration costs recorded in the second quarter of 2015.  Tracked costs, which have no earnings impact, were unchanged.

Operations and Maintenance expense decreased for the six months ended June 30, 2016, as compared to the same period in 2015, driven by a $2.8 million decrease in non-tracked costs, which was primarily attributable to lower operational vehicle costs, reimbursement of legal fees in the second quarter of 2016, and the absence in 2016 of integration costs recorded in the second quarter of 2015, partially offset by higher storm restoration costs.  Tracked costs, which have no earnings impact, increased $0.2 million that was primarily attributable to higher transmission expenses offset by lower bad debt expense.

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

Amortization of Regulatory (Liabilities)/Assets, 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 (Liabilities)/Assets, Net increased for the three months ended June 30, 2016 and decreased for the six months ended June 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.   

Energy Efficiency Programs expense (the costs of which are tracked) increased for the three months ended June 30, 2016 and decreased for the six months ended June 30, 2016, as compared to the same periods in 2015, due primarily to the deferral adjustment, which reflects the actual costs of energy efficiency programs, compared to the estimated amounts billed to customers.  The deferral adjusts expense to match the energy efficiency programs revenue.  CL&P is allowed to recover its costs for state energy policy initiatives and expanded energy efficiency programs.

Taxes Other Than Income Taxes expense increased for the three and six months ended June 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 June 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($3.7 million), higher state taxes ($0.7 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($2 million).

Income Tax Expense increased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($13.7 million), higher state taxes ($1.8 million), and items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($2.6 million), partially offset by the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.9 million).

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EARNINGS SUMMARY

CL&P's earnings increased $4.1 million for the three months ended June 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, and 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.  These favorable earnings impacts were partially offset by higher operations and maintenance expense, higher property taxes and a higher effective tax rate.  

CL&P's earnings increased $21.9 million for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to an increase in transmission earnings driven by the absence in 2016 of the 2015 FERC ROE complaint proceedings reserve charge as well as a higher transmission rate base, and 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.  These favorable earnings impacts were partially offset by higher property taxes and higher depreciation expense.  

LIQUIDITY

Cash totaled $9.4 million as of June 30, 2016, compared with $1.1 million as of December 31, 2015.

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 June 30, 2016 and December 31, 2015 was 0.66 percent and 0.72 percent, respectively.  As of June 30, 2016 and December 31, 2015, there were intercompany loans from Eversource parent to CL&P of $93 million and $277.4 million, respectively.

CL&P had cash flows provided by operating activities of $429.4 million in the first half of 2016, as compared to $270 million in the same period of 2015.  The increase in operating cash flows was due primarily to the timing of collections and payments related to our working capital items, including accounts receivable and accounts payable.  In addition, there was an increase of $48.7 million in income tax refunds received in the first half of 2016, as compared to the same period in 2015.

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 investments totaled $288.6 million in the first half of 2016.

Financing activities included $99.8 million in common stock dividends paid to Eversource parent in the first half of 2016.

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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 six months ended June 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  

			For the Six Months Ended June 30,
(Millions of Dollars)							Increase/
			2016		2015		(Decrease)		Percent
Operating Revenues			$	1,205.5	$	1,384.0	$	(178.5)	(12.9)	%
Operating Expenses:
	Purchased Power and Transmission			473.5		685.0		(211.5)	(30.9)
	Operations and Maintenance			183.7		145.3		38.4	26.4
	Depreciation			104.5		97.7		6.8	7.0
	Amortization of Regulatory Assets/(Liabilities), Net			8.7		(12.9)		21.6	(a)
	Energy Efficiency Programs			128.1		97.2		30.9	31.8
	Taxes Other Than Income Taxes			66.7		60.8		5.9	9.7
		Total Operating Expenses		965.2		1,073.1		(107.9)	(10.1)
Operating Income				240.3		310.9		(70.6)	(22.7)
Interest Expense				41.1		38.2		2.9	7.6
Other Income, Net				2.5		3.1		(0.6)	(19.4)
Income Before Income Tax Expense				201.7		275.8		(74.1)	(26.9)
Income Tax Expense				79.0		110.3		(31.3)	(28.4)
Net Income			$	122.7	$	165.5	$	(42.8)	(25.9)	%
(a) Percent greater than 100 not shown as it is not meaningful.
Operating Revenues
NSTAR Electric's retail sales volumes were as follows:
			For the Six Months Ended June 30,
			2016		2015		Decrease		Percent
Retail Sales Volumes in GWh				9,781		10,261		(480)	(4.7)	%

NSTAR Electric's Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased by $178.5 million for the six months ended June 30, 2016, as compared to the same period in 2015.  

Base distribution revenues:  Base distribution revenues, excluding LBR, decreased $14.2 million due primarily to weather impacts.  The impact 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, as well as increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, were the primary drivers of a 4.7 percent decrease in sales volumes during the first half of 2016.  NSTAR Electric is allowed to recover LBR related to reductions in sales volumes as a result of successful energy efficiency programs.

Also contributing to the decrease in operating revenues in the first half 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 of LBR related to 2009 through 2011 energy efficiency programs.  

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.  Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs ($250.6 million) driven by decreased average retail rates and lower sales volumes.  Partially offsetting this decrease was an increase in cost recovery related to energy efficiency programs ($31.3 million), an increase in retail transmission charges ($27.3 million) and an increase in net metering revenues ($13.3 million).

Transmission revenues increased by $12.6 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.

Purchased Power and Transmission expense includes costs associated with purchasing electricity on behalf of NSTAR 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 six months ended June 30 2016, as compared to the same period in 2015, due primarily to the following:  

(Millions of Dollars)	(Decrease)/Increase
Purchased Power Costs	$	(249.7)
Transmission Costs		38.2
Total Purchased Power and Transmission	$	(211.5)

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Included in purchased power costs are the costs associated with NSTAR 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 in transmission costs was primarily the result of an increase in the RNS costs billed by ISO-NE.

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 six months ended June 30, 2016, as compared to the same period in 2015, driven by a $34.3 million increase in non-tracked costs, which was primarily attributable to the absence in 2016 of the resolution of the basic service bad debt adder mechanism recorded in the first quarter of 2015 ($24.2 million), higher vegetation management expense and higher storm restoration costs.  Additionally, there was a $4.1 million increase in tracked costs, which have no earnings impact, that was primarily attributable to higher employee-related expenses and higher bad debt expense.

Depreciation expense increased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to higher utility plant in service balances.  

Amortization of Regulatory Assets/(Liabilities), Net 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 revenues for the six months ended June 30, 2016, as compared to the same period in 2015.  The deferral adjusts expense 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 customers in rates and have no impact on earnings.

Energy Efficiency Programs expense (the costs of which are tracked) increased for the six months ended June 30, 2016, 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 an increase in 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 six months ended June 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.

Interest Expense increased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to higher interest on long-term debt ($4.7 million) as a result of new debt issuances, partially offset by lower interest on regulatory deferral mechanisms ($1.6 million).

Income Tax Expense decreased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to lower pre-tax earnings ($26 million), lower state taxes ($4 million), the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.9 million), and various other items ($0.4 million).

EARNINGS SUMMARY

NSTAR Electric's earnings decreased $42.8 million for the six months ended June 30, 2016, as compared to the same period in 2015, 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 operations and maintenance expense and higher depreciation expense.  These unfavorable 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.

LIQUIDITY

NSTAR Electric had cash flows provided by operating activities of $165.1 million in the first half of 2016, as compared to $207.6 million in the same period of 2015.  The decrease in operating cash flows was due primarily to changes related to our working capital items, including the timing of collections and payments of receivables and accounts payable.  In addition, there was a $36.6 million reduction in income tax refunds received in the first half of 2016, as compared to the same period in 2015.  Also contributing to the decrease in operating cash flows was an increase in Pension Plan contributions of $12.8 million in the first half of 2016, as compared to the same period in 2015.  Partially offsetting these unfavorable impacts was the timing of regulatory recoveries resulting primarily from the decrease in purchased power costs and energy efficiency programs.

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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 six months ended June 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  

			For the Six Months Ended June 30,
							Increase/
(Millions of Dollars)			2016		2015		(Decrease)		Percent
Operating Revenues			$	460.8	$	526.7	$	(65.9)	(12.5)	%
Operating Expenses:
	Purchased Power, Fuel and Transmission			95.9		147.5		(51.6)	(35.0)
	Operations and Maintenance			123.0		134.9		(11.9)	(8.8)
	Depreciation			56.9		51.4		5.5	10.7
	Amortization of Regulatory Assets, Net			0.3		27.2		(26.9)	(98.9)
	Energy Efficiency Programs			6.9		7.1		(0.2)	(2.8)
	Taxes Other Than Income Taxes			44.0		41.3		2.7	6.5
		Total Operating Expenses		327.0		409.4		(82.4)	(20.1)
Operating Income				133.8		117.3		16.5	14.1
Interest Expense				25.0		22.9		2.1	9.2
Other Income, Net				0.4		1.6		(1.2)	(75.0)
Income Before Income Tax Expense				109.2		96.0		13.2	13.8
Income Tax Expense				41.9		36.0		5.9	16.4
Net Income			$	67.3	$	60.0	$	7.3	12.2	%
Operating Revenues
PSNH's retail sales volumes were as follows:
			For the Six Months Ended June 30,
			2016		2015		Decrease		Percent
Retail Sales Volumes in GWh				3,818		3,911		(93)	(2.4)	%

PSNH's Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased by $65.9 million for the six months ended June 30, 2016, as compared to the same period in 2015.

Base distribution revenues:  Base distribution revenues decreased $0.9 million due primarily to weather impacts.  The impact 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, as well as increased customer energy conservation efforts, including those resulting from company-sponsored energy efficiency programs, were the primary drivers of a 2.4 percent decrease in sales volumes during the first half of 2016.  Partially offsetting this decrease was a $3.5 million increase as a result of a distribution rate increase effective July 1, 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.  Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs and a reduction in wholesale generation revenues for the six months ended June 30, 2016, as compared to the same period of 2015 ($58.2 million), driven by lower sales volumes and decreased average retail rates.  In addition, retail transmission charges decreased by $8.6 million for the six months ended June 30, 2016, as compared to the same period in 2015.

Transmission revenues increased by $11.5 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.

Purchased Power, Fuel and Transmission expense includes costs associated with 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 for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to the following:

(Millions of Dollars)	(Decrease)/Increase
Purchased Power and Generation Fuel Costs	$	(54.5)
Transmission Costs		2.9
Total Purchased Power, Fuel and Transmission	$	(51.6)

In order to meet the demand of customers who have not migrated to third party suppliers, PSNH procures power through long-term power supply contracts and short-term purchases and spot purchases in the competitive New England wholesale power market and/or produces power through its own generation.  The decrease in purchased power and generation fuel costs was due primarily to a decrease in the amount of electricity generated by PSNH facilities.

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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 for the six months ended June 30, 2016, as compared to the same period in 2015, driven by an $8.7 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 $3.2 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, which have no earnings impact.

Depreciation expense increased for the six months ended June 30, 2016, 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) includes the deferral 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 six months ended June 30, 2016, as compared to the same period in 2015, was due primarily to a decrease in the default energy service charge.  The deferral adjusts expense to match the corresponding revenues.  

Taxes Other Than Income Taxes expense increased for the six months ended June 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.

Income Tax Expense increased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($4.6 million), higher state taxes ($0.5 million), and various other items ($1.1 million), partially offset by the excess tax benefit due to the adoption of new accounting guidance related to share-based payment transactions ($0.3 million).

EARNINGS SUMMARY

PSNH's earnings increased $7.3 million for the six months ended June 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, lower operations and maintenance expense, higher generation earnings and the impact of the distribution rate increase effective July 1, 2015.  These favorable earnings impacts were partially offset by lower retail sales volumes and higher depreciation expense.

LIQUIDITY

PSNH had cash flows provided by operating activities of $204.3 million in the first half of 2016, as compared to $150.5 million in the same period in 2015.  The increase in operating cash flows was due primarily to income tax refunds of $37.3 million received in the first half of 2016, compared to income tax payments of $9.4 million the same period in 2015.  In addition, the timing of payments related to our accounts payable favorably impacted the first half of 2016 operating cash flows, as compared to the same period in 2015.  Partially offsetting these favorable impacts were an increase in Pension Plan contributions of $10.2 million in the first half of 2016 and the use of fuel inventories.       

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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 six months ended June 30, 2016 and 2015 included in this combined Quarterly Report on Form 10-Q:  

			For the Six Months Ended June 30,
							Increase/
(Millions of Dollars)			2016		2015		(Decrease)		Percent
Operating Revenues			$	244.5	$	278.1	$	(33.6)	(12.1)	%
Operating Expenses:
	Purchased Power and Transmission			72.2		112.7		(40.5)	(35.9)
	Operations and Maintenance			43.9		39.9		4.0	10.0
	Depreciation			22.9		21.2		1.7	8.0
	Amortization of Regulatory Assets, Net			2.2		7.3		(5.1)	(69.9)
	Energy Efficiency Programs			21.2		20.6		0.6	2.9
	Taxes Other Than Income Taxes			19.8		18.9		0.9	4.8
		Total Operating Expenses		182.2		220.6		(38.4)	(17.4)
Operating Income				62.3		57.5		4.8	8.3
Interest Expense				12.1		13.1		(1.0)	(7.6)
Other Income/(Loss), Net				-		1.8		(1.8)	(100.0)
Income Before Income Tax Expense				50.2		46.2		4.0	8.7
Income Tax Expense				20.1		18.8		1.3	6.9
Net Income			$	30.1	$	27.4	$	2.7	9.9	%
Operating Revenues
WMECO's retail sales volumes were as follows:
			For the Six Months Ended June 30,
			2016		2015		Decrease		Percent
Retail Sales Volumes in GWh				1,707		1,775		(68)	(3.8)	%

WMECO's Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased by $33.6 million for the six months ended June 30, 2016, as compared to the same period in 2015.

Fluctuations in WMECO's sales volumes do not impact the level of base distribution revenue realized or earnings due to the DPU approved revenue decoupling mechanism.  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.  

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 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, low income assistance programs, and restructuring and stranded cost recovery revenues.  Tracked revenues decreased due primarily to a decrease in energy supply costs ($41.2 million) driven by decreased average retail rates and lower sales volumes.

Transmission revenues increased by $8.6 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 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 six months ended June 30 2016, as compared to the same period in 2015, due primarily to the following:

(Millions of Dollars)	(Decrease)/Increase
Purchased Power Costs	$	(44.0)
Transmission Costs		3.5
Total Purchased Power and Transmission	$	(40.5)

Included in purchased power costs are the costs associated with 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.

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 six months ended June 30, 2016, as compared to the same period in 2015, driven by a $2.2 million increase in tracked costs, which have no earnings impact, that was primarily attributable to the deferral of RECs generated and sold by the WMECO solar program, and an increase of $1.8 million in non-tracked costs that was primarily attributable to higher employee-related expenses and higher bad debt expense.

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Depreciation expense increased for the six months ended June 30, 2016, 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 six months ended June 30, 2016, as compared to the same period in 2015, due to the timing of refunds or recovery of tracked costs from customers in rates.  Energy and energy related costs are recovered from customers in rates and have no impact on earnings.

Other Income/(Loss), Net decreased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to lower AFUDC on equity funds ($0.9 million) and a decrease in net gains related to the deferred compensation plans ($0.7 million).

Income Tax Expense increased for the six months ended June 30, 2016, as compared to the same period in 2015, due primarily to higher pre-tax earnings ($1.4 million), partially offset by various other items ($0.1 million).

EARNINGS SUMMARY

WMECO's earnings increased $2.7 million for the six months ended June 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 depreciation expense and higher property and other tax expense.

LIQUIDITY

WMECO had cash flows provided by operating activities of $95.9 million for the first half of June 30, 2016, as compared to $43.9 million in the same period of 2015.  The increase in operating cash flows was due primarily to the timing of collections of accounts receivable and payments related to accounts payable and the timing of regulatory recoveries relating to purchased power costs.  In addition, the increase in operating cash flows was due to an increase of $17.3 million in income tax refunds in the first half of 2016, as compared to the same period in 2015.

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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 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 June 30, 2016, our Regulated companies did not hold collateral (letters of credit) from counterparties related to our standard service contracts.  As of June 30, 2016, Eversource had $15.6 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 and Qualitative Disclosures about Market Risk," in Eversource's 2015 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 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 June 30, 2016 to determine whether they are effective in ensuring that the disclosure of required information is made timely and in accordance with the Securities Exchange Act of 1934 and the rules and regulations of the SEC.  This evaluation was made under management's supervision and with management's participation, including the principal executive officer and principal financial officer as of the end of the period covered by this 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.

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

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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 Proceedings," and elsewhere in our 2015 Form 10-K.  These disclosures are incorporated herein by reference.  

The Yankee Companies each filed lawsuits against the DOE in August 2013 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 awarding 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 by the Yankee Companies in Phase III.  The decision became final on July 18, 2016.  

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"), and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the "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' 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 it has valid defenses to the claims and intends to defend it 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 and NSTAR Electric’s financial position, results of operations, or cash flows.

The Conservation Law Foundation (CLF) filed a citizens’ suit under the provisions of the federal Clean Air Act against PSNH alleging permitting violations at the company’s Merrimack generating station, as described under the caption "Conservation Law Foundation v. PSNH" in Part I, Item 3, "Legal Proceedings" of our 2015 Form 10-K.  On July 15, 2016, CLF and PSNH jointly filed a status report in the United States District Court, District of New Hampshire.  By way of the status report, CLF notified the Court that it would initiate voluntary dismissal of the lawsuit with prejudice if there are no requests for rehearing of the NHPUC order approving the Agreement that, among other things, instructs PSNH to begin the process to divest its generation assets.  On August 1, 2016, the NHPUC order became final and, as a result, and per the terms of the previously filed status report, on August 3, 2016, CLF dismissed this lawsuit with prejudice.  For further information, see "Financial Condition and Business Analysis – Regulatory Developments and Rate Matters – New Hampshire – Generation Divestiture" in this Management’s Discussion and Analysis of Financial Condition and Results of Operations.  

Other than as set forth above, 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 Form 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 Statements," in Item 2, "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 Factors," in our 2015 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 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 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)
April 1 – April 30, 2016	105,894	$	58.27	-	-
May 1 – May 31, 2016	8,598		56.70	-	-
June 1  – June 30, 2016	99,935		58.11	-	-
Total	214,427	$	58.13	-	-

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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)

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)

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)

*4

A Form of 2.70% Debenture Due 2026 (Exhibit 4, NSTAR Electric Company Current Report on Form 8-K filed May 31, 2016, File No. 001-02301)

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

57

Listing of Exhibits (WMECO)

*4

Eighth Supplemental Indenture between WMECO and The Bank of New York Trust Company, N.A., as Trustee, dated as of June 1, 2016 (Exhibit 4.1, WMECO Current Report on Form 8-K filed June 29, 2016, File No. 000-07624)

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

58

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
August 5, 2016	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

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.

	THE CONNECTICUT LIGHT AND POWER COMPANY
August 5, 2016	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

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.

	NSTAR ELECTRIC COMPANY
August 5, 2016	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

59

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.

	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
August 5, 2016	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

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.

	WESTERN MASSACHUSETTS ELECTRIC COMPANY
August 5, 2016	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

60

EX-12

Eversource Energy and Subsidiaries													Exhibit 12
Ratio of Earnings to Fixed Charges
(Unaudited)
		Six Months
		Ended
		June 30,		For the Years Ended December 31,
(Thousands of Dollars)		2016		2015		2014		2013		2012 (a)		2011
Earnings, as defined:
	Net income	$	451,562	$	886,004	$	827,065	$	793,689	$	533,077	$	400,513
	Income tax expense		271,742		539,967		468,297		426,941		274,926		170,953
	Equity in (earnings)/loss of equity investees		213		(883)		(1,044)		(1,318)		(1,154)		(671)
	Dividends received from equity investees		-		-		-		582		733		940
	Fixed charges, as below		212,102		397,392		386,451		362,403		353,616		275,948
	Less: Interest capitalized (including AFUDC)		(4,524)		(7,221)		(5,766)		(4,062)		(5,261)		(11,758)
	Preferred dividend security requirements of   consolidated subsidiaries (pre-tax)		(6,265)		(12,532)		(12,532)		(12,803)		(11,715)		(9,265)
Total earnings, as defined		$	924,830	$	1,802,727	$	1,662,471	$	1,565,432	$	1,144,222	$	826,660
Fixed charges, as defined:
	Interest Expense	$	198,703	$	372,420	$	362,106	$	338,699	$	329,945	$	250,425
	Rental interest factor		2,610		5,219		6,047		6,839		6,695		4,500
	Preferred dividend security requirements of   consolidated subsidiaries (pre-tax)		6,265		12,532		12,532		12,803		11,715		9,265
	Interest capitalized (including AFUDC)		4,524		7,221		5,766		4,062		5,261		11,758
Total fixed charges, as defined		$	212,102	$	397,392	$	386,451	$	362,403	$	353,616	$	275,948
Ratio of Earnings to Fixed Charges			4.36		4.54		4.30		4.32		3.24		3.00
(a) NSTAR amounts were included in Eversource beginning April 10, 2012.

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of Eversource Energy (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	James J. Judge
	James J. Judge
	President and Chief Executive Officer
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of Eversource Energy (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of Eversource Energy (the registrant) for the period ending June 30, 2016 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, President and Chief Executive Officer of the registrant, and Philip J. Lembo, Senior Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	President and Chief Executive Officer

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer

Date:  August 5, 2016

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

EX-12

The Connecticut Light and Power Company													Exhibit 12
Ratio of Earnings to Fixed Charges
(Unaudited)
		Six Months
		Ended
		June 30,		For the Years Ended December 31,
(Thousands of Dollars)		2016		2015		2014		2013		2012		2011
Earnings, as defined:
	Net income	$	169,921	$	299,360	$	287,754	$	279,412	$	209,725	$	250,164
	Income tax expense		98,427		177,396		133,451		141,663		94,437		90,033
	Equity in earnings of equity investees		(18)		(31)		(32)		(67)		(40)		(16)
	Dividends received from equity investees		-		-		-		289		-		-
	Fixed charges, as below		76,490		153,751		152,513		139,929		139,982		140,311
	Less: Interest capitalized (including AFUDC)		(1,350)		(2,630)		(1,867)		(2,249)		(2,456)		(3,317)
Total earnings, as defined		$	343,470	$	627,846	$	571,819	$	558,977	$	441,648	$	477,175
Fixed charges, as defined:
	Interest Expense	$	72,477	$	145,795	$	147,421	$	133,650	$	133,127	$	132,727
	Rental interest factor		2,663		5,326		3,225		4,030		4,399		4,267
	Interest capitalized (including AFUDC)		1,350		2,630		1,867		2,249		2,456		3,317
Total fixed charges, as defined		$	76,490	$	153,751	$	152,513	$	139,929	$	139,982	$	140,311
Ratio of Earnings to Fixed Charges			4.49		4.08		3.75		3.99		3.16		3.40

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of The Connecticut Light and Power Company (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	James J. Judge
	James J. Judge
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of The Connecticut Light and Power Company (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of The Connecticut Light and Power Company (the registrant) for the period ending June 30, 2016 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, Chairman of the registrant, and Philip J. Lembo, Senior Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	Chairman

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer

Date:  August 5, 2016

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

EX-12

NSTAR Electric Company and Subsidiary													Exhibit 12
Ratio of Earnings to Fixed Charges
(Unaudited)
		Six Months
		Ended
		June 30,		For the Years Ended December 31,
(Thousands of Dollars)		2016		2015		2014		2013		2012		2011
Earnings, as defined:
	Net income	$	122,661	$	344,542	$	303,088	$	268,546	$	190,242	$	252,494
	Income tax expense		79,053		228,044		201,981		172,866		123,966		165,686
	Equity in (earnings)/loss of equity investees		82		(343)		(408)		(550)		(412)		(501)
	Dividends received from equity investees		-		-		-		344		286		676
	Fixed charges, as below		44,488		80,536		82,503		73,115		72,364		76,219
	Less: Interest capitalized (including AFUDC)		(1,779)		(1,980)		(2,027)		(511)		(259)		(185)
Total earnings, as defined		$	244,505	$	650,799	$	585,137	$	513,810	$	386,187	$	494,389
Fixed charges, as defined:
	Interest Expense	$	41,104	$	75,347	$	77,878	$	70,383	$	70,054	$	69,427
	Rental interest factor		1,605		3,209		2,598		2,221		2,051		6,607
	Interest capitalized (including AFUDC)		1,779		1,980		2,027		511		259		185
Total fixed charges, as defined		$	44,488	$	80,536	$	82,503	$	73,115	$	72,364	$	76,219
Ratio of Earnings to Fixed Charges			5.50		8.08		7.09		7.03		5.34		6.49

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of NSTAR Electric Company (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	James J. Judge
	James J. Judge
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of NSTAR Electric Company (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of NSTAR Electric Company (the registrant) for the period ending June 30, 2016 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, Chairman of the registrant, and Philip J. Lembo, Senior Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	Chairman

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer

Date:  August 5, 2016

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

EX-12

Public Service Company of New Hampshire and Subsidiary													Exhibit 12
Ratio of Earnings to Fixed Charges
(Unaudited)
		Six Months
		Ended
		June 30,		For the Years Ended December 31,
(Thousands of Dollars)		2016			2015		2014		2013		2012		2011
Earnings, as defined:
	Net income	$	67,313	$	114,442	$	113,944	$	111,397	$	96,882	$	100,267
	Income tax expense		41,899		73,060		72,135		71,101		60,993		49,945
	Equity in earnings of equity investees		(4)		(8)		(8)		(12)		(8)		(7)
	Dividends received from equity investees		-		-		-		42		-		-
	Fixed charges, as below		25,915		47,949		46,530		47,318		52,769		52,111
	Less: Interest capitalized (including AFUDC)		(445)		(994)		(640)		(500)		(1,579)		(7,064)
Total earnings, as defined		$	134,678	$	234,449	$	231,961	$	229,346	$	209,057	$	195,252
Fixed charges, as defined:
	Interest Expense	$	24,987	$	45,990	$	45,349	$	46,176	$	50,228	$	44,147
	Rental interest factor		483		965		541		642		962		900
	Interest capitalized (including AFUDC)		445		994		640		500		1,579		7,064
Total fixed charges, as defined		$	25,915	$	47,949	$	46,530	$	47,318	$	52,769	$	52,111
Ratio of Earnings to Fixed Charges			5.20		4.89		4.99		4.85		3.96		3.75

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of Public Service Company of New Hampshire (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	James J. Judge
	James J. Judge
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of Public Service Company of New Hampshire (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of Public Service Company of New Hampshire (the registrant) for the period ending June 30, 2016 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, Chairman of the registrant, and Philip J. Lembo, Senior Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	Chairman

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer

Date:  August 5, 2016

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

EX-12

Western Massachusetts Electric Company													Exhibit 12
Ratio of Earnings to Fixed Charges
(Unaudited)
		Six Months
		Ended
		June 30,		For the Years Ended December 31,
(Thousands of Dollars)		2016		2015		2014		2013		2012		2011
Earnings, as defined:
	Net income	$	30,092	$	56,506	$	57,819	$	60,438	$	54,503	$	43,054
	Income tax expense		20,071		36,970		37,268		37,368		32,140		23,186
	Equity in earnings of equity investees		(5)		(8)		(8)		(18)		(11)		(4)
	Dividends received from equity investees		-		-		-		80		-		-
	Fixed charges, as below		12,733		26,553		26,202		26,316		28,162		25,079
	Less: Interest capitalized (including AFUDC)		(298)		(1,042)		(864)		(498)		(534)		(534)
Total earnings, as defined		$	62,593	$	118,979	$	120,417	$	123,686	$	114,260	$	90,781
Fixed charges, as defined:
	Interest Expense	$	12,075	$	24,792	$	24,931	$	24,851	$	26,634	$	23,612
	Rental interest factor		360		719		407		967		994		933
	Interest capitalized (including AFUDC)		298		1,042		864		498		534		534
Total fixed charges, as defined		$	12,733	$	26,553	$	26,202	$	26,316	$	28,162	$	25,079
Ratio of Earnings to Fixed Charges			4.92		4.48		4.60		4.70		4.06		3.62

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James J. Judge, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of Western Massachusetts Electric Company (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	James J. Judge
	James J. Judge
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Philip J. Lembo, certify that:

1.

I have reviewed this Quarterly Report on Form 10-Q of Western Massachusetts Electric Company (the registrant);

2.

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

3.

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

4.

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

(a)

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

(b)

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

(c)

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

(d)

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

5.

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

(a)

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

(b)

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

Date:  August 5, 2016

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of Western Massachusetts Electric Company (the registrant) for the period ending June 30, 2016 as filed with the Securities and Exchange Commission (the Report), we, James J. Judge, Chairman of the registrant, and Philip J. Lembo, Senior Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2)

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the registrant.

/s/	James J. Judge
	James J. Judge
	Chairman

/s/	Philip J. Lembo
	Philip J. Lembo
	Senior Vice President, Chief Financial Officer and Treasurer

Date:  August 5, 2016

A signed original of this written statement required by Section 906, or other document authenticating, acknowledging, or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to the registrant and will be retained by the registrant and furnished to the Securities and Exchange Commission or its staff upon request.

XML

DOCUMENT AND ENTITY INFORMATION	6 Months Ended
	Jun. 30, 2016 USD ($) shares
Document And Entity [Line Items]
Entity Registrant Name	Eversource Energy
Document Period End Date	Jun. 30, 2016
Document Type	10-Q
Entity Central Index Key	0000072741
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding | shares	317,207,036
Entity Public Float | $	$ 18,939,770,997
Entity Filer Category	Large Accelerated Filer
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	Yes
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Amendment Flag	false
trading	ES
The Connecticut Light And Power Company [Member]
Document And Entity [Line Items]
Entity Registrant Name	The Connecticut Light and Power Company
Entity Central Index Key	0000023426
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Public Service Company Of New Hampshire [Member]
Document And Entity [Line Items]
Entity Registrant Name	Public Service Company of New Hampshire
Entity Central Index Key	0000315256
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Western Massachusetts Electric Company [Member]
Document And Entity [Line Items]
Entity Registrant Name	Western Massachusetts Electric Company
Entity Central Index Key	0000106170
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
NSTAR Electric Company [Member]
Document And Entity [Line Items]
Entity Registrant Name	NSTAR Electric Company
Entity Central Index Key	0000013372
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer

XML

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Current Assets:
Cash	$ 38,726	$ 23,947
Receivables, Net	806,340	775,480
Unbilled Revenues	203,824	202,647
Taxes Receivable	103,926	305,359
Fuel, Materials and Supplies	292,547	336,476
Regulatory Assets Current	863,360	845,843
Prepayments and Other Current Assets	106,561	129,034
Total Current Assets	2,415,284	2,618,786
Property, Plant and Equipment, Net	20,448,475	19,892,441
Deferred Debits and Other Assets:
Regulatory Assets Long Term	3,661,578	3,737,960
Goodwill	3,519,401	3,519,401
Marketable Securities	518,750	516,478
Other Long-Term Assets	319,175	295,243
Total Deferred Debits and Other Assets	8,018,904	8,069,082
Total Assets	30,882,663	30,580,309
Current Liabilities:
Notes Payable	767,000	1,160,953
Long-Term Debt - Current Portion	178,883	228,883
Accounts Payable - Current	631,566	813,646
Obligations to Third Party Suppliers	133,943	128,564
Regulatory Liability Current	119,413	107,759
Other Liabilities - Current	472,964	549,985
Total Current Liabilities	2,303,769	2,989,790
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	5,398,926	5,147,678
Regulatory Liabilities Long-Term	527,678	513,595
Long-Term Derivative Liabilities	381,572	337,102
Accrued Pension, SERP and PBOP	1,294,548	1,407,288
Other Long-Term Liabilities	875,270	871,499
Total Deferred Credits and Other Liabilities	8,477,994	8,277,162
Capitalization:
Long-Term Debt	9,435,924	8,805,574
Noncontrolling Interest in Consolidated Subsidiary:
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	155,568	155,568
Common Shareholders' Equity:
Common Stock	1,669,392	1,669,313
Capital Surplus, Paid In	6,252,514	6,262,368
Retained Earnings	2,962,843	2,797,355
Accumulated Other Comprehensive Loss	(65,364)	(66,844)
Treasury Stock	(309,977)	(309,977)
Common Shareholders' Equity	10,509,408	10,352,215
Total Capitalization	20,100,900	19,313,357
Total Liabilities and Capitalization	30,882,663	30,580,309
The Connecticut Light And Power Company [Member]
Current Assets:
Cash	9,449	1,057
Receivables, Net	370,982	352,536
Accounts Receivable from Affiliated Companies	9,703	21,214
Unbilled Revenues	99,822	99,879
Taxes Receivable	12,498	137,643
Regulatory Assets Current	312,160	268,318
Materials and Supplies	52,538	43,124
Prepayments and Other Current Assets	15,826	32,234
Total Current Assets	882,978	956,005
Property, Plant and Equipment, Net	7,336,577	7,156,809
Deferred Debits and Other Assets:
Regulatory Assets Long Term	1,368,897	1,369,028
Other Long-Term Assets	121,477	111,115
Total Deferred Debits and Other Assets	1,490,374	1,480,143
Total Assets	9,709,929	9,592,957
Current Liabilities:
Notes Payable To Affiliated Companies	93,000	277,400
Long-Term Debt - Current Portion	150,000	0
Accounts Payable - Current	219,332	267,764
Accounts Payable to Affiliated Companies	60,169	66,456
Obligations to Third Party Suppliers	61,532	60,746
Regulatory Liability Current	63,287	61,155
Derivative Liabilities - Current	91,603	91,820
Other Liabilities - Current	122,886	110,631
Total Current Liabilities	861,809	935,972
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,922,428	1,820,865
Regulatory Liabilities Long-Term	80,617	74,830
Long-Term Derivative Liabilities	380,643	336,189
Accrued Pension, SERP and PBOP	247,419	271,056
Other Long-Term Liabilities	131,883	133,446
Total Deferred Credits and Other Liabilities	2,762,990	2,636,386
Capitalization:
Long-Term Debt	2,614,878	2,763,682
Noncontrolling Interest in Consolidated Subsidiary:
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	116,200	116,200
Common Shareholders' Equity:
Common Stock	60,352	60,352
Capital Surplus, Paid In	2,056,389	1,910,663
Retained Earnings	1,237,620	1,170,278
Accumulated Other Comprehensive Loss	(309)	(576)
Common Shareholders' Equity	3,354,052	3,140,717
Total Capitalization	6,085,130	6,020,599
Total Liabilities and Capitalization	9,709,929	9,592,957
NSTAR Electric Company [Member]
Current Assets:
Cash	3,391	3,346
Receivables, Net	254,376	229,936
Accounts Receivable from Affiliated Companies	12,241	4,034
Unbilled Revenues	43,115	29,464
Taxes Receivable	21,564	70,236
Fuel, Materials and Supplies	40,292	75,487
Regulatory Assets Current	316,715	348,408
Prepayments and Other Current Assets	9,510	11,448
Total Current Assets	701,204	772,359
Property, Plant and Equipment, Net	5,788,659	5,655,458
Deferred Debits and Other Assets:
Regulatory Assets Long Term	1,112,099	1,112,977
Other Long-Term Assets	61,886	62,467
Total Deferred Debits and Other Assets	1,173,985	1,175,444
Total Assets	7,663,848	7,603,261
Current Liabilities:
Notes Payable	329,000	62,500
Long-Term Debt - Current Portion	0	200,000
Accounts Payable - Current	146,868	228,250
Accounts Payable to Affiliated Companies	46,174	38,648
Obligations to Third Party Suppliers	61,538	56,718
Renewable Portfolio Standards Compliance Obligation	44,239	104,847
Regulatory Liability Current	6,923	3,281
Other Liabilities - Current	58,770	72,007
Total Current Liabilities	693,512	766,251
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,809,408	1,760,339
Regulatory Liabilities Long-Term	267,809	264,352
Accrued Pension, SERP and PBOP	194,734	209,153
Other Long-Term Liabilities	124,877	120,939
Total Deferred Credits and Other Liabilities	2,396,828	2,354,783
Capitalization:
Long-Term Debt	2,077,687	1,829,766
Noncontrolling Interest in Consolidated Subsidiary:
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	43,000	43,000
Common Shareholders' Equity:
Common Stock	0	0
Capital Surplus, Paid In	995,378	995,378
Retained Earnings	1,456,919	1,613,538
Accumulated Other Comprehensive Loss	524	545
Common Shareholders' Equity	2,452,821	2,609,461
Total Capitalization	4,573,508	4,482,227
Total Liabilities and Capitalization	7,663,848	7,603,261
Public Service Company Of New Hampshire [Member]
Current Assets:
Cash	1,084	1,733
Receivables, Net	77,389	77,546
Accounts Receivable from Affiliated Companies	3,938	2,352
Unbilled Revenues	38,275	38,207
Taxes Receivable	8,848	43,128
Fuel, Materials and Supplies	151,475	156,868
Regulatory Assets Current	122,879	104,971
Prepayments and Other Current Assets	19,570	24,302
Total Current Assets	423,458	449,107
Property, Plant and Equipment, Net	2,925,288	2,855,363
Deferred Debits and Other Assets:
Regulatory Assets Long Term	238,612	257,873
Other Long-Term Assets	34,886	34,176
Total Deferred Debits and Other Assets	273,498	292,049
Total Assets	3,622,244	3,596,519
Current Liabilities:
Notes Payable To Affiliated Companies	120,900	231,300
Accounts Payable - Current	96,059	87,925
Accounts Payable to Affiliated Companies	21,049	24,214
Regulatory Liability Current	5,986	6,898
Other Liabilities - Current	37,264	43,921
Total Current Liabilities	281,258	394,258
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	746,785	705,894
Regulatory Liabilities Long-Term	47,283	47,851
Accrued Pension, SERP and PBOP	75,721	89,579
Other Long-Term Liabilities	50,318	50,746
Total Deferred Credits and Other Liabilities	920,107	894,070
Capitalization:
Long-Term Debt	1,071,532	1,071,017
Common Shareholders' Equity:
Common Stock	0	0
Capital Surplus, Paid In	831,634	748,634
Retained Earnings	523,414	494,901
Accumulated Other Comprehensive Loss	(5,701)	(6,361)
Common Shareholders' Equity	1,349,347	1,237,174
Total Capitalization	2,420,879	2,308,191
Total Liabilities and Capitalization	3,622,244	3,596,519
Western Massachusetts Electric Company [Member]
Current Assets:
Cash	1,421	834
Receivables, Net	54,685	50,912
Accounts Receivable from Affiliated Companies	9,139	18,633
Unbilled Revenues	13,928	15,065
Taxes Receivable	422	33,407
Regulatory Assets Current	57,660	56,166
Prepayments and Other Current Assets	8,598	7,882
Total Current Assets	145,853	182,899
Property, Plant and Equipment, Net	1,616,305	1,575,306
Deferred Debits and Other Assets:
Regulatory Assets Long Term	124,804	135,010
Other Long-Term Assets	27,625	24,875
Total Deferred Debits and Other Assets	152,429	159,885
Total Assets	1,914,587	1,918,090
Current Liabilities:
Notes Payable To Affiliated Companies	53,700	143,400
Accounts Payable - Current	32,783	58,364
Accounts Payable to Affiliated Companies	19,935	19,896
Obligations to Third Party Suppliers	10,336	9,654
Renewable Portfolio Standards Compliance Obligation	11,251	6,395
Regulatory Liability Current	11,256	13,122
Other Liabilities - Current	11,556	13,878
Total Current Liabilities	150,817	264,709
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	487,389	470,539
Regulatory Liabilities Long-Term	13,280	11,597
Accrued Pension, SERP and PBOP	12,135	19,515
Other Long-Term Liabilities	40,175	36,819
Total Deferred Credits and Other Liabilities	552,979	538,470
Capitalization:
Long-Term Debt	566,885	517,329
Common Shareholders' Equity:
Common Stock	10,866	10,866
Capital Surplus, Paid In	426,398	391,398
Retained Earnings	209,232	198,140
Accumulated Other Comprehensive Loss	(2,590)	(2,822)
Common Shareholders' Equity	643,906	597,582
Total Capitalization	1,210,791	1,114,911
Total Liabilities and Capitalization	$ 1,914,587	$ 1,918,090

XML

CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Operating Revenues	$ 1,767,184	$ 1,817,061	$ 3,822,819	$ 4,330,491
Operating Expenses:
Purchased Power and Transmission	581,260	685,118	1,336,119	1,847,167
Operations and Maintenance	320,714	316,641	640,850	650,024
Depreciation	176,507	163,668	350,492	327,505
Amortization of Regulatory Assets/(Liabilities), Net	(8,716)	(1,166)	12,281	59,438
Energy Efficiency Programs	119,667	101,850	256,842	248,452
Taxes Other Than Income Taxes	154,330	138,935	314,277	288,415
Total Operating Expenses	1,343,762	1,405,046	2,910,861	3,421,001
Operating Income	423,422	412,015	911,958	909,490
Interest Expense:
Total Interest Expense	100,492	92,259	198,703	187,102
Other Income [Abstract]
Other Income/(Loss), Net	8,038	12,899	10,049	18,626
Income Before Income Tax Expense	330,968	332,655	723,304	741,014
Income Tax Expense	125,439	123,268	271,742	276,494
Net Income	205,529	209,387	451,562	464,520
Net Income Attributable to Noncontrolling Interests	1,880	1,880	3,759	3,759
Net Income Attributable to Controlling Interests	$ 203,649	$ 207,507	$ 447,803	$ 460,761
Earnings Per Share Basic And Diluted	$ 0.64	$ 0.65	$ 1.41	$ 1.45
Common Stock Dividends Per Share Declared	$ 0.45	$ 0.42	$ 0.89	$ 0.84
Weighted Average Common Shares Outstanding:
Basic	317,785,495	317,613,166	317,651,319	317,352,004
Diluted	318,476,699	318,559,568	318,478,876	318,525,378
The Connecticut Light And Power Company [Member]
Operating Revenues	$ 679,787	$ 666,554	$ 1,415,103	$ 1,471,471
Operating Expenses:
Purchased Power and Transmission	234,504	253,180	507,104	586,799
Operations and Maintenance	122,532	118,687	233,375	236,044
Depreciation	57,532	52,191	114,500	105,094
Amortization of Regulatory Assets/(Liabilities), Net	(2,988)	(7,530)	6,891	40,776
Energy Efficiency Programs	35,498	33,963	73,589	76,770
Taxes Other Than Income Taxes	70,568	62,102	146,030	130,181
Total Operating Expenses	517,646	512,593	1,081,489	1,175,664
Operating Income	162,141	153,961	333,614	295,807
Interest Expense:
Total Interest Expense	35,978	36,124	72,477	72,748
Other Income [Abstract]
Other Income/(Loss), Net	6,275	4,062	7,211	6,221
Income Before Income Tax Expense	132,438	121,899	268,348	229,280
Income Tax Expense	49,563	43,129	98,427	81,276
Net Income	82,875	78,770	169,921	148,004
NSTAR Electric Company [Member]
Operating Revenues	591,301	617,196	1,205,517	1,384,004
Operating Expenses:
Purchased Power and Transmission	219,189	283,129	473,525	684,995
Operations and Maintenance	88,954	69,430	183,650	145,254
Depreciation	52,571	48,949	104,457	97,716
Amortization of Regulatory Assets/(Liabilities), Net	3,971	(7,336)	8,654	(12,901)
Energy Efficiency Programs	61,922	41,733	128,165	97,150
Taxes Other Than Income Taxes	34,194	29,876	66,750	60,841
Total Operating Expenses	460,801	465,781	965,201	1,073,055
Operating Income	130,500	151,415	240,316	310,949
Interest Expense:
Total Interest Expense	20,216	17,781	41,104	38,227
Other Income [Abstract]
Other Income/(Loss), Net	2,836	2,533	2,502	3,136
Income Before Income Tax Expense	113,120	136,167	201,714	275,858
Income Tax Expense	44,953	54,204	79,053	110,335
Net Income	68,167	81,963	122,661	165,523
Public Service Company Of New Hampshire [Member]
Operating Revenues	218,517	241,875	460,807	526,722
Operating Expenses:
Purchased Power and Transmission	45,653	47,938	95,867	147,516
Operations and Maintenance	63,788	76,468	123,001	134,895
Depreciation	28,644	25,751	56,879	51,397
Amortization of Regulatory Assets/(Liabilities), Net	(8,186)	12,050	332	27,181
Energy Efficiency Programs	3,259	3,356	6,879	7,128
Taxes Other Than Income Taxes	22,287	22,249	44,082	41,331
Total Operating Expenses	155,445	187,812	327,040	409,448
Operating Income	63,072	54,063	133,767	117,274
Interest Expense:
Total Interest Expense	12,526	11,662	24,987	22,935
Other Income [Abstract]
Other Income/(Loss), Net	282	1,245	432	1,628
Income Before Income Tax Expense	50,828	43,646	109,212	95,967
Income Tax Expense	19,573	15,701	41,899	35,977
Net Income	31,255	27,945	67,313	59,990
Western Massachusetts Electric Company [Member]
Operating Revenues	116,396	125,194	244,491	278,058
Operating Expenses:
Purchased Power and Transmission	32,665	43,055	72,228	112,716
Operations and Maintenance	22,088	20,104	43,893	39,889
Depreciation	11,476	10,848	22,847	21,223
Amortization of Regulatory Assets/(Liabilities), Net	992	3,336	2,203	7,264
Energy Efficiency Programs	10,347	9,519	21,203	20,594
Taxes Other Than Income Taxes	9,600	9,398	19,833	18,833
Total Operating Expenses	87,168	96,260	182,207	220,519
Operating Income	29,228	28,934	62,284	57,539
Interest Expense:
Total Interest Expense	6,072	6,291	12,075	13,112
Other Income [Abstract]
Other Income/(Loss), Net	104	1,245	(46)	1,819
Income Before Income Tax Expense	23,260	23,888	50,163	46,246
Income Tax Expense	9,995	9,693	20,071	18,807
Net Income	$ 13,265	$ 14,195	$ 30,092	$ 27,439

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net Income	$ 205,529	$ 209,387	$ 451,562	$ 464,520
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	534	509	1,068	1,018
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	1,061	(1,248)	1,325	(1,116)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	(1,784)	1,120	(913)	2,074
Other Comprehensive Income (Loss), Net of Tax, Total	(189)	381	1,480	1,976
Comprehensive Income Attributable to Noncontrolling Interests	(1,880)	(1,880)	(3,759)	(3,759)
Comprehensive Income	203,460	207,888	449,283	462,737
The Connecticut Light And Power Company [Member]
Net Income	82,875	78,770	169,921	148,004
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	111	111	222	222
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	36	(43)	45	(39)
Other Comprehensive Income (Loss), Net of Tax, Total	147	68	267	183
Comprehensive Income	83,022	78,838	170,188	148,187
NSTAR Electric Company [Member]
Net Income	68,167	81,963	122,661	165,523
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	(11)	(2)	(21)	(182)
Other Comprehensive Income (Loss), Net of Tax, Total	(11)	(2)	(21)	(182)
Comprehensive Income	68,156	81,961	122,640	165,341
Public Service Company Of New Hampshire [Member]
Net Income	31,255	27,945	67,313	59,990
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	291	290	581	581
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	63	(75)	79	(67)
Other Comprehensive Income (Loss), Net of Tax, Total	354	215	660	514
Comprehensive Income	31,609	28,160	67,973	60,504
Western Massachusetts Electric Company [Member]
Net Income	13,265	14,195	30,092	27,439
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	110	84	219	169
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	10	(12)	13	(11)
Other Comprehensive Income (Loss), Net of Tax, Total	120	72	232	158
Comprehensive Income	$ 13,385	$ 14,267	$ 30,324	$ 27,597

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CONSOLIDATED STATEMENT OF CASH FLOWS - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Operating Activities:
Net Income	$ 451,562	$ 464,520
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	350,492	327,505
Deferred Income Tax Expense (Benefit)	250,851	176,800
Pension, SERP and PBOP Expense	22,659	48,432
Pension and PBOP Contributions	(65,929)	(31,032)
Regulatory Over/(Under) Recoveries, Net	(5,768)	(73,547)
Amortization of Regulatory Assets/(Liabilities), Net	12,281	59,438
Other	(10,808)	(38,521)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(76,751)	(123,984)
Increase Decrease in Fuel, Materials and Supplies	43,930	60,044
Taxes Receivable/(Accrued)	230,075	214,577
Accounts Payable	(151,996)	(228,176)
Other Current Assets and Liabilities, Net	(72,160)	9,226
Net Cash Flows Provided by Operating Activities	978,438	865,282
Investing Activities:
Investments in Property, Plant and Equipment	(869,168)	(740,379)
Proceeds from Sales of Marketable Securities	327,581	427,990
Purchases of Marketable Securities	(322,244)	(408,242)
Other Investing Activities	(2,991)	4,821
Net Cash Flows Used in Investing Activities	(866,822)	(715,810)
Financing Activities:
Cash Dividends on Common Stock	(282,314)	(264,936)
Cash Dividends on Preferred Stock	(3,759)	(3,759)
Increase/(Decrease) in Short-Term Debt	(393,953)	(449,375)
Issuance of Long-Term Debt	800,000	750,000
Retirements of Long-Term Debt	(200,000)	(166,577)
Other Financing Activities	(16,811)	(17,059)
Net Cash Flows Provided by/(Used in) Financing Activities	(96,837)	(151,706)
Net Increase/(Decrease) in Cash	14,779	(2,234)
Cash - Beginning of Year	23,947	38,703
Cash - End of Year	38,726	36,469
The Connecticut Light And Power Company [Member]
Operating Activities:
Net Income	169,921	148,004
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	114,500	105,094
Deferred Income Tax Expense (Benefit)	97,913	30,145
Pension, SERP and PBOP Expense, Net of Contributions	3,325	7,079
Regulatory Over/(Under) Recoveries, Net	(40,386)	(55,302)
Amortization of Regulatory Assets/(Liabilities), Net	6,891	40,776
Other	(4,477)	(2,432)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(26,729)	(73,279)
Taxes Receivable/(Accrued)	145,852	123,051
Accounts Payable	(38,137)	(55,192)
Other Current Assets and Liabilities, Net	774	2,085
Net Cash Flows Provided by Operating Activities	429,447	270,029
Investing Activities:
Investments in Property, Plant and Equipment	(288,630)	(242,346)
Proceeds From Sale Of Property Plant And Equipment	9,047
Other Investing Activities	205	(1,362)
Net Cash Flows Used in Investing Activities	(279,378)	(243,708)
Financing Activities:
Cash Dividends on Common Stock	(99,800)	(98,000)
Cash Dividends on Preferred Stock	(2,779)	(2,779)
Issuance of Long-Term Debt		300,000
Increase/(Decrease) in Notes Payable to Affiliate	(184,400)	(47,800)
Retirements of Long-Term Debt		(162,000)
Capital Contributions from NU Parent	145,700
Other Financing Activities	(398)	(8,871)
Net Cash Flows Provided by/(Used in) Financing Activities	(141,677)	(19,450)
Net Increase/(Decrease) in Cash	8,392	6,871
Cash - Beginning of Year	1,057	2,356
Cash - End of Year	9,449	9,227
NSTAR Electric Company [Member]
Operating Activities:
Net Income	122,661	165,523
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	104,457	97,716
Deferred Income Tax Expense (Benefit)	48,505	61,734
Pension, SERP and PBOP Expense, Net of Contributions	(13,236)	(264)
Regulatory Over/(Under) Recoveries, Net	26,277	(96,290)
Amortization of Regulatory Assets/(Liabilities), Net	8,654	(12,901)
Other	(3,978)	(28,653)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(56,140)	(91,753)
Increase Decrease in Fuel, Materials and Supplies	35,194	17,595
Taxes Receivable/(Accrued)	45,608	100,661
Accounts Payable	(88,774)	(30,839)
Other Current Assets and Liabilities, Net	(64,084)	25,076
Net Cash Flows Provided by Operating Activities	165,144	207,605
Investing Activities:
Investments in Property, Plant and Equipment	(199,824)	(188,103)
Other Investing Activities		53
Net Cash Flows Used in Investing Activities	(199,824)	(188,050)
Financing Activities:
Cash Dividends on Common Stock	(278,300)	(99,000)
Cash Dividends on Preferred Stock	(980)	(980)
Increase/(Decrease) in Short-Term Debt	266,500	75,200
Issuance of Long-Term Debt	250,000
Retirements of Long-Term Debt	(200,000)	(4,700)
Other Financing Activities	(2,495)	0
Net Cash Flows Provided by/(Used in) Financing Activities	34,725	(29,480)
Net Increase/(Decrease) in Cash	45	(9,925)
Cash - Beginning of Year	3,346	12,773
Cash - End of Year	3,391	2,848
Public Service Company Of New Hampshire [Member]
Operating Activities:
Net Income	67,313	59,990
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	56,879	51,397
Deferred Income Tax Expense (Benefit)	45,976	47,454
Regulatory Over/(Under) Recoveries, Net	(10,740)	(3,089)
Amortization of Regulatory Assets/(Liabilities), Net	332	27,181
Other	(8,484)	8,726
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(5,247)	(6,597)
Increase Decrease in Fuel, Materials and Supplies	5,394	11,019
Taxes Receivable/(Accrued)	33,840	(20,414)
Accounts Payable	20,417	(21,362)
Other Current Assets and Liabilities, Net	(1,422)	(3,792)
Net Cash Flows Provided by Operating Activities	204,258	150,513
Investing Activities:
Investments in Property, Plant and Equipment	(138,713)	(140,171)
Other Investing Activities	172	169
Net Cash Flows Used in Investing Activities	(138,541)	(140,002)
Financing Activities:
Cash Dividends on Common Stock	(38,800)	(53,000)
Increase/(Decrease) in Notes Payable to Affiliate	(110,400)	43,000
Capital Contributions from NU Parent	83,000
Other Financing Activities	(166)	(182)
Net Cash Flows Provided by/(Used in) Financing Activities	(66,366)	(10,182)
Net Increase/(Decrease) in Cash	(649)	329
Cash - Beginning of Year	1,733	489
Cash - End of Year	1,084	818
Western Massachusetts Electric Company [Member]
Operating Activities:
Net Income	30,092	27,439
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	22,847	21,223
Deferred Income Tax Expense (Benefit)	17,155	12,503
Regulatory Over/(Under) Recoveries, Net	(2,651)	(7,911)
Amortization of Regulatory Assets/(Liabilities), Net	2,203	7,264
Other	(2,547)	(3,598)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	6,500	(11,593)
Taxes Receivable/(Accrued)	32,985	18,774
Accounts Payable	(13,176)	(21,056)
Other Current Assets and Liabilities, Net	2,502	859
Net Cash Flows Provided by Operating Activities	95,910	43,904
Investing Activities:
Investments in Property, Plant and Equipment	(71,459)	(62,966)
Proceeds from Sales of Marketable Securities	1,484	49,739
Purchases of Marketable Securities	(1,457)	(50,118)
Net Cash Flows Used in Investing Activities	(71,432)	(63,345)
Financing Activities:
Cash Dividends on Common Stock	(19,000)	(18,600)
Issuance of Long-Term Debt	50,000
Increase/(Decrease) in Notes Payable to Affiliate	(89,700)	39,200
Capital Contributions from NU Parent	35,000
Other Financing Activities	(191)	(16)
Net Cash Flows Provided by/(Used in) Financing Activities	(23,891)	20,584
Net Increase/(Decrease) in Cash	587	1,143
Cash - Beginning of Year	834	0
Cash - End of Year	$ 1,421	$ 1,143

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Significant Accounting Policies [Text Block]

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 condensedfinancial statements.

1.       SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

A.       Basis of Presentation

EversourceEnergy is a public utility holding company primarily engaged, through its wholly owned regulated utility subsidiaries, in the energy delivery business.Eversource Energy's wholly owned regulated utility subsidiaries consist of CL&P, NSTAR Electric, PSNH, WMECO, Yankee Gas and NSTAR Gas.Eversource provides energy delivery service to approximately 3.6 million electric and natural gas customers through these six regulated utilities in Connecticut, Massachusetts and New Hampshire.

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 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 Statements and Supplementary Data," of the Eversource 2015 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, CL&P's, NSTAR Electric's, PSNH's and WMECO's financial position as of June 30, 2016 and December31, 2015, the results of operations andcomprehensive incomefor the three and six months ended June 30, 2016 and 2015, and the cash flows for the six months ended June 30, 2016 and 2015. The results of operations andcomprehensive incomefor the three and six months ended June 30, 2016 and 2015 and the cash flows for the six months ended June 30, 2016 and 2015 are not necessarily indicative of the results expected for a full year.

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

Access Northeast is a natural gas pipeline and storage project (the "Project") being developed jointly by Eversource, Spectra Energy Corp and National Grid. Access Northeast will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes. Eversource and Spectra Energy Corp each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid. The total projected cost for both the pipeline and the LNG storage is expected to be approximately $3 billion, to be funded in proportion to ownership interest (approximately $1.2 billion by Eversource), with anticipated in-service dates commencing in November 2018. Eversource's cumulative equity investment in the Project as of June 30, 2016 of $20.7 millionis presented in Other Long-Term Assets.

Eversource's utility subsidiaries' distribution (including generation) and transmission businesses are subject to rate-regulation that is based on cost recovery and meets the criteria for application of accounting guidance for entities with rate-regulated operations, which considers the effect of regulation on the differences in the timing of the recognition of certain revenues and expenses from those of other businesses and industries. See Note2, "Regulatory Accounting," for further information.

Certain reclassifications of prior period data were made in the accompanyingfinancial statements to conform to the current period presentationand as a result of the adoption of new accounting guidance. See Note 1B,"Summary of Significant Accounting Policies – Accounting Standards," for further information.

B.       Accounting Standards

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

In January 2016, the FASB issued ASU 2016-01, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Liabilities, which is required to be implemented in the first quarter of 2018. The Company is reviewing the requirements of the ASU. The ASU will remove the available-for-sale designation for equity securities, whereby changes in fair value are recorded in other comprehensive income in shareholders' equity, and will require changes in fair value of all equity securities to be recorded in earnings beginning on January 1, 2018, with the unrealized gain or loss on available-for-sale equity securities as of that date reclassified to retained earnings as a cumulative effect of adoption. The fair value of available-for-sale equity securities subject to this guidance as of June 30, 2016 was approximately $48million. The remaining available-for-sale equity securities included in marketable securities on the balance sheet are held in nuclear decommissioning trusts and are subject to regulatory accounting treatment and will not be impacted by this guidance. Implementation of the ASU for other financial instruments is not expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

In February 2016, the FASB issued ASU 2016-02, Leases, which changes existing lease accounting guidance and is required to be applied in the first quarter of 2019, with earlier application permitted. The ASU is required to be implemented for leases beginning on the date of initial application. For prior periods presented, leases are required to be recognized and measured using a modified retrospective approach.  The Company is reviewing the requirements of ASU 2016-02, including balance sheet recognition of leases previously deemed operating leases, and expects to implement them in the first quarter of 2019.

Recently Adopted Accounting Standards: In April 2015, the FASB issued ASU 2015-05, Intangibles – Goodwill and Other – Internal-Use Software: Customer's Accounting for Fees Paid in a Cloud Computing Arrangement, effective for annual periods, including interim periods, beginning after December 15, 2015. The ASU amends existing guidance on intangibles and internal-use software and may be applied prospectively or retrospectively. On January 1, 2016, Eversource adopted the new accounting guidance prospectively, which did not have an impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

In March 2016, the FASB issued ASU 2016-09, Compensation - Stock Compensation: Improvements to Employee Share-Based Payment Accounting. The ASU is intended to simplify some aspects of the accounting for share-based payment transactions. The ASU is required to be implemented in the first quarter of 2017, with early adoption permitted. The Company implemented this guidance in the first quarter of 2016. Beginning in the first quarter of 2016, the excess tax benefits associated with the distribution of stock compensation awards, previously recognized in Capital Surplus, Paid In in Common Shareholders' Equity on the balance sheet, are recognized in income tax expense in the income statement. The implementation reduced income tax expense by $2.7million for the six months ended June 30, 2016. Also, beginning in 2016,in the statement of cash flows, the excess tax benefits are presented as an operating activity rather than 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 six months ended June 30, 2016 and 2015 were $9.1million and $9.7 million, respectively, and are included in Other Financing Activities on the statements of cash flows.

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 assessment of collectability from customers. Management continuously assesses the collectability of receivables and adjusts collectability estimates based on actual experience. Receivable balances are written off against the provision for uncollectible accounts when the customer accounts are terminated and these balances are deemed to be uncollectible.

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

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

	Total Provision for Uncollectible Accounts				Uncollectible Hardship
(Millions of Dollars)	As of June 30, 2016		As of December 31, 2015		As of June 30, 2016		As of December 31, 2015
Eversource	$	205.5	$	190.7	$	123.7	$	118.5
CL&P		82.7		79.5		66.2		68.1
NSTAR Electric		56.9		52.6		28.6		25.3
PSNH		9.6		8.7		-		-
WMECO		15.3		14.0		8.4		7.4

D.       Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases or normal sales" (normal) and to the marketable securities held in trusts. Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill and AROs, and the estimated fair value of preferred stock and long-term debt.

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

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

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

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

Determination of Fair Value: The valuation techniques and inputs used in Eversource's fair value measurements are described in Note 4, "Derivative Instruments," Note 5, "Marketable Securities," and Note 9, "Fair Value of Financial Instruments," to thefinancial 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 equity method investees. Investment income/(loss) primarily relates to debt and equity securities held in trust. For further information, see Note 5, "Marketable Securities," to the financial statements.

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 Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015		June 30, 2016		June 30, 2015
Eversource	$	37.5	$	33.2	$	79.8	$	75.1
CL&P		33.6		29.5		69.6		62.5

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

G.	Supplemental Cash Flow Information
Non-cash investing activities include plant additions included in Accounts Payable as follows:
(Millions of Dollars)		As of June 30, 2016		As of June 30, 2015
Eversource		$	186.3	$	142.3
CL&P			59.5		47.2
NSTAR Electric			38.5		29.5
PSNH			31.1		25.6
WMECO			14.6		13.7

XML

REGULATORY ACCOUNTING

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Public Utilities Disclosure [Text Block]

2.       REGULATORY ACCOUNTING

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

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

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

	As of June 30, 2016		As of December 31, 2015
(Millions of Dollars)	Eversource		Eversource
Benefit Costs	$	1,754.1	$	1,828.2
Derivative Liabilities		413.7		388.0
Income Taxes, Net		644.3		650.9
Storm Restoration Costs		428.9		436.9
Goodwill-related		474.6		484.9
Regulatory Tracker Mechanisms		562.5		526.5
Contractual Obligations - Yankee Companies		117.3		134.4
Other Regulatory Assets		129.6		134.0
Total Regulatory Assets		4,525.0		4,583.8
Less: Current Portion		863.4		845.8
Total Long-Term Regulatory Assets	$	3,661.6	$	3,738.0

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Benefit Costs	$	383.2	$	477.0	$	160.0	$	77.9	$	413.6	$	479.9	$	164.2	$	84.9
Derivative Liabilities		411.3		2.4		-		-		380.8		1.3		-		-
Income Taxes, Net		442.5		86.3		28.2		31.0		444.4		85.7		34.5		31.8
Storm Restoration Costs		269.5		117.7		21.7		20.0		271.4		110.9		31.5		23.1
Goodwill-related		-		407.5		-		-		-		416.3		-		-
Regulatory Tracker Mechanisms		96.6		287.0		120.5		41.5		45.1		311.0		101.2		40.1
Other Regulatory Assets		78.0		50.9		31.1		12.1		82.0		56.3		31.5		11.3
Total Regulatory Assets		1,681.1		1,428.8		361.5		182.5		1,637.3		1,461.4		362.9		191.2
Less: Current Portion		312.2		316.7		122.9		57.7		268.3		348.4		105.0		56.2
Total Long-Term Regulatory Assets	$	1,368.9	$	1,112.1	$	238.6	$	124.8	$	1,369.0	$	1,113.0	$	257.9	$	135.0

Regulatory Costs in Other Long-Term Assets:The Regulated companies had $83million (including $2.6million for CL&P, $38.5million for NSTAR Electric,$5.5 million for PSNH and $19.4million for WMECO) and $75.3million (including $3.1million for CL&P, $35.4million for NSTAR Electric, $4.8 million for PSNH, and $16.7million for WMECO) of additional regulatory costs as of June 30, 2016 and December 31, 2015, 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 June 30, 2016		As of December 31, 2015
(Millions of Dollars)	Eversource		Eversource
Cost of Removal	$	448.5	$	437.1
Regulatory Tracker Mechanisms		104.4		99.7
AFUDC - Transmission		65.7		66.1
Other Regulatory Liabilities		28.5		18.5
Total Regulatory Liabilities		647.1		621.4
Less: Current Portion		119.4		107.8
Total Long-Term Regulatory Liabilities	$	527.7	$	513.6

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Cost of Removal	$	30.4	$	261.6	$	46.6	$	4.6	$	24.1	$	257.4	$	47.2	$	2.8
Regulatory Tracker Mechanisms		50.0		6.1		3.2		11.1		56.2		3.3		3.4		12.9
AFUDC - Transmission		50.9		6.0		-		8.8		51.5		5.7		-		8.9
Other Regulatory Liabilities		12.6		1.0		3.5		0.1		4.2		1.3		4.2		0.1
Total Regulatory Liabilities		143.9		274.7		53.3		24.6		136.0		267.7		54.8		24.7
Less: Current Portion		63.3		6.9		6.0		11.3		61.2		3.3		6.9		13.1
Total Long-Term Regulatory Liabilities	$	80.6	$	267.8	$	47.3	$	13.3	$	74.8	$	264.4	$	47.9	$	11.6

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PROPERTY, PLANT AND ACCUMULATED DEPRECIATION

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Property Plant And Equipment Disclosure [Text Block]

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 June 30, 2016		As of December 31, 2015
(Millions of Dollars)		Eversource		Eversource
Distribution - Electric		$	13,425.4	$	13,054.8
Distribution - Natural Gas			2,819.9		2,727.2
Transmission - Electric			7,896.3		7,691.9
Generation			1,218.3		1,194.1
Electric and Natural Gas Utility			25,359.9		24,668.0
Other (1)			583.5		558.6
Property, Plant and Equipment, Gross			25,943.4		25,226.6
Less: Accumulated Depreciation
	Electric and Natural Gas Utility		(6,342.9)		(6,141.1)
	Other		(274.5)		(255.6)
Total Accumulated Depreciation			(6,617.4)		(6,396.7)
Property, Plant and Equipment, Net			19,326.0		18,829.9
Construction Work in Progress			1,122.5		1,062.5
Total Property, Plant and Equipment, Net		$	20,448.5	$	19,892.4

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

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Distribution	$	5,471.5	$	5,279.1	$	1,883.8	$	831.0	$	5,377.2	$	5,100.5	$	1,804.8	$	812.3
Transmission		3,691.2		2,205.3		972.0		977.9		3,618.0		2,131.3		928.2		964.9
Generation		-		-		1,182.4		35.9		-		-		1,158.1		36.0
Property, Plant and Equipment, Gross		9,162.7		7,484.4		4,038.2		1,844.8		8,995.2		7,231.8		3,891.1		1,813.2
Less: Accumulated Depreciation		(2,089.2)		(1,962.7)		(1,217.3)		(323.0)		(2,041.9)		(1,886.8)		(1,171.0)		(307.0)
Property, Plant and Equipment, Net		7,073.5		5,521.7		2,820.9		1,521.8		6,953.3		5,345.0		2,720.1		1,506.2
Construction Work in Progress		263.1		267.0		104.4		94.5		203.5		310.5		135.3		69.1
Total Property, Plant and Equipment, Net	$	7,336.6	$	5,788.7	$	2,925.3	$	1,616.3	$	7,156.8	$	5,655.5	$	2,855.4	$	1,575.3

As of June 30, 2016, PSNH had $1.2billion in gross generation utility plant assets and related Accumulated Depreciation of $542.8million. These generation assets are the subject of a divestiture agreement whereby PSNH agreed to divest of these generation assets. The NHPUC approved the divestiture agreement on July 1, 2016. The NHPUC is in the process of selecting an auction adviser to assist with the divestiture. Upon completion of the divestiture process, all remaining costs not recovered by the sale of these assets (stranded costs) will be recovered via bonds that will be secured by a non-bypassable charge or through recoveries in rates billed to PSNH's customers. See Note 8E, "Commitments and Contingencies – PSNH Generation Restructuring," for further information.

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DERIVATIVE INSTRUMENTS

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Derivative Instruments and Hedging Activities Disclosure [Text Block]

4.       DERIVATIVE INSTRUMENTS

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

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

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

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

		As of June 30, 2016						As of December 31, 2015
		Commodity Supply				Net Amount		Commodity Supply				Net Amount
		and Price Risk				Recorded as		and Price Risk					Recorded as
(Millions of Dollars)		Management		Netting (1)		a Derivative		Management		Netting (1)		a Derivative
Current Derivative Assets:
Level 2:
	Eversource	$	3.5	$	-	$	3.5	$	-	$	-	$	-
Level 3:
	Eversource		17.5		(10.8)		6.7		16.7		(10.9)		5.8
	CL&P		16.6		(10.8)		5.8		16.7		(10.9)		5.8
	NSTAR Electric		0.9		-		0.9		-		-		-
Long-Term Derivative Assets:
Level 2:
	Eversource	$	-	$	-	$	-	$	0.1	$	-	$	0.1
Level 3:
	Eversource		70.1		(14.8)		55.3		62.0		(19.3)		42.7
	CL&P		69.9		(14.8)		55.1		60.7		(19.3)		41.4
	NSTAR Electric		0.2		-		0.2		1.3		-		1.3
Current Derivative Liabilities:
Level 2:
	Eversource	$	-	$	-	$	-	$	(5.8)	$	-	$	(5.8)
Level 3:
	Eversource		(93.0)		-		(93.0)		(92.3)		-		(92.3)
	CL&P		(91.6)		-		(91.6)		(91.8)		-		(91.8)
	NSTAR Electric		(1.4)		-		(1.4)		(0.5)		-		(0.5)
Long-Term Derivative Liabilities:
Level 3:
	Eversource	$	(381.6)	$	-	$	(381.6)	$	(337.1)	$	-	$	(337.1)
	CL&P		(380.6)		-		(380.6)		(336.2)		-		(336.2)
	NSTAR Electric		(1.0)		-		(1.0)		(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 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 June 30, 2016 and December 31, 2015, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately 7.1 million and 9.1 million MMBtu of natural gas, respectively.

For the three months ended June 30, 2016 and 2015, there were losses of $42.9million and $36.6 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource's derivative contracts. For the six months ended June 30, 2016 and 2015, these losses were $74.4 million and $50.1 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 of the contract.

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

The following is a summary of Eversource's, including CL&P's and NSTAR Electric's, Level 3 derivative contracts and the range of the significant unobservable inputs utilized in the valuations over the duration of the contracts:

	As of June 30, 2016						As of December 31, 2015
		Range				Period Covered		Range				Period Covered
Capacity Prices:
Eversource	$	5.50	-	13.23	per kW-Month	2017 - 2026	$	10.81	-	15.82	per kW-Month	2016 - 2026
CL&P	$	5.50	-	13.23	per kW-Month	2020 - 2026	$	10.81	-	12.60	per kW-Month	2019 - 2026
NSTAR Electric	$	8.50	-	12.11	per kW-Month	2017 - 2018	$	10.81	-	15.82	per kW-Month	2016 - 2019
Forward Reserve:
Eversource, CL&P	$	2.00			per kW-Month	2016 - 2024	$	2.00			per kW-Month	2016 - 2024
REC Prices:
Eversource, NSTAR Electric	$	38	-	42	per REC	2016 - 2018	$	45	-	51	per REC	2016 - 2018

Exit price premiums of 4percent through 21percent are also applied on these contracts and reflect the uncertainty and illiquidity premiums that would be required based on the most recent market activity available for similar type contracts.

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 June 30,
	2016						2015
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(387.7)	$	(385.1)	$	(2.6)	$	(406.8)	$	(403.3)	$	(3.5)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities		(46.6)		(46.8)		0.2		(37.1)		(36.8)		(0.3)
Settlements		21.7		20.6		1.1		21.5		19.9		1.6
Fair Value as of End of Period	$	(412.6)	$	(411.3)	$	(1.3)	$	(422.4)	$	(420.2)	$	(2.2)
	For the Six Months Ended June 30,
	2016						2015
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		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 Losses Included in Regulatory Assets and Liabilities		(76.6)		(72.2)		(4.4)		(49.2)		(48.9)		(0.3)
Settlements		44.9		41.7		3.2		42.2		39.6		2.6
Fair Value as of End of Period	$	(412.6)	$	(411.3)	$	(1.3)	$	(422.4)	$	(420.2)	$	(2.2)

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MARKETABLE SECURITIES

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Marketable Securities [Text Block]

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 securitiesas trading securities, with the changes in fair values recorded in Other Income, Net on the statements of income.As of June 30, 2016 and December 31, 2015, these securities were classified as Level 1 in the fair value hierarchy and totaled $10.6million and $14.2 million, respectively.For the three months ended June 30, 2016 and 2015, net gains on these securities of $0.2 million and $0.5 million, respectively,and for the six months ended June 30, 2016 and 2015, net gains of $0.5 million and $2.1 million, respectively,were recorded in Other Income, Net on the statements of income.Dividend income is recorded in Other Income, Net when dividends are declared.

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

		As of June 30, 2016								As of December 31, 2015
				Pre-Tax		Pre-Tax						Pre-Tax		Pre-Tax
Eversource		Amortized		Unrealized		Unrealized				Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains		Losses		Fair Value		Cost		Gains		Losses		Fair Value
	Debt Securities	$	261.0	$	8.4	$	-	$	269.4	$	256.5	$	4.5	$	(0.6)	$	260.4
	Equity Securities		207.8		58.5		(2.3)		264.0		215.3		59.2		(3.4)		271.1

Eversource's debt and equity securities include CYAPC's and YAEC's marketable securities held in nuclear decommissioning trusts of $439.5million and $436.9 million as of June 30, 2016 and December 31, 2015, 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 six months ended June 30, 2016 and 2015. Factors considered in determining whether a credit loss exists include the duration and severity of the impairment, adverse conditions specifically affecting the issuer, and the payment history, ratings and rating changes of the security. For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated.

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

Contractual Maturities: As of June 30, 2016, the contractual maturities of available-for-sale debt securities were as follows:

Eversource	Amortized
(Millions of Dollars)	Cost		Fair Value
Less than one year (1)	$	27.2	$	27.2
One to five years		61.6		62.4
Six to ten years		45.4		47.2
Greater than ten years		126.8		132.6
Total Debt Securities	$	261.0	$	269.4

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 June 30, 2016		As of December 31, 2015
Level 1:
	Mutual Funds and Equities	$	274.6	$	285.3
	Money Market Funds		21.1		26.9
Total Level 1		$	295.7	$	312.2
Level 2:
	U.S. Government Issued Debt Securities (Agency and Treasury)	$	70.8	$	46.6
	Corporate Debt Securities		39.5		43.9
	Asset-Backed Debt Securities		18.8		20.0
	Municipal Bonds		109.9		111.4
	Other Fixed Income Securities		9.3		11.6
Total Level 2		$	248.3	$	233.5
Total Marketable Securities		$	544.0	$	545.7

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.

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SHORT TERM DEBT

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Short Term Debt Text Block

6.SHORT-TERM AND LONG-TERM DEBT

Commercial Paper Programs and Credit Agreements: Eversource parent has a $1.45 billion commercial paper program allowingEversource parent to issue commercial paper as a form of short-term debt. As of June 30, 2016 and December 31, 2015, Eversource parent had $438 million and approximately$1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $1.0 billion and $351.5 million of available borrowing capacity as of June 30, 2016 and December 31, 2015, respectively. The weighted-average interest rate on these borrowings as of June 30, 2016 and December 31, 2015 was 0.66 percent and 0.72 percent, respectively. As of June 30, 2016, there were intercompany loans from Eversource parent of $93million to CL&P, $120.9 million to PSNH and $53.7 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 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, which terminates on September 4, 2020. The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program.

NSTAR Electric has a $450 million commercial paper programallowing NSTAR Electric to issue commercial paper as a form of short-term debt. As of June 30, 2016 and December 31, 2015, NSTAR Electric had $329 million and $62.5 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $121 million and $387.5 million of available borrowing capacity as of June 30, 2016 and December 31, 2015, respectively. The weighted-average interest rate on these borrowings as of June 30, 2016 and December 31, 2015was 0.44 percent and 0.40 percent, respectively. NSTAR Electric is a party to a five-year $450 million revolving credit facility, which terminates on September 4, 2020. The revolving credit facility serves to backstop NSTAR Electric's $450 million commercial paper program.

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 balance sheets.

Long-Term Debt Issuances: In March 2016, Eversource parent issued $250 million of 2.50 percent Series I Senior Notes due to mature in 2021 and $250 million of 3.35 percent Series J Senior Notes due to mature in 2026. 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 issued $250 million of 2.70 percent debentures, due to mature in 2026. The proceeds, net of issuance costs, were used to repay short-term borrowings under the NSTAR Electric commercial paper programand 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. The proceeds, net of issuance costs, were used to repay short-term borrowings.

Long-Term Debt Repayments:In May 2016, NSTAR Electric repaid at maturity $200 million variable rate debentures, using short-term borrowings.

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PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

7.Pension Benefits and Postretirement Benefits Other than Pensions

Eversource Service sponsorsa defined benefit retirement plan (Pension Plan)that covers eligible employees, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO. In addition to the Pension Plan, Eversource maintains non-qualified defined benefit retirement plans sponsored by Eversource Service (SERP Plans), which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees.Eversource Service also sponsors defined benefit postretirement plans that provide certain benefits, primarily medical, dental and life insurance, to retired employees that met certain age and service eligibility requirements, including, among others, employees of CL&P, NSTAR Electric, PSNH and WMECO(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 5.14 percent for the Pension and PBOP plans, respectively. The discount rates used to estimate the 2016 interest cost were 3.80 percent and 3.72 percent for the Pension and PBOP plans, respectively. Thetotal 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 June 30, 2016 was approximately $11.5 million and $2.5 million for the Pension and PBOP plans, respectively, and approximately $23 million and $5 millionfor the six months ended June 30, 2016, respectively.

On August 5, 2016, the Company amended its PBOP plan. The amendment standardized separate benefit structures that existed within the plan and made other benefit changes. Overall, the plan amendment is expected to reduce the PBOP plan's accumulated projected benefit obligation by approximately $220 million. The PBOP liability will be remeasured as of August 5, 2016, and the PBOP expense for the remainder of 2016 will be recorded using updated assumptions and actuarial calculations.

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 portion 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 Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015(1)		June 30, 2016		June 30, 2015(1)
Service Cost	$	18.7	$	22.8	$	37.9	$	45.9
Interest Cost		46.4		56.9		92.8		113.3
Expected Return on Plan Assets		(79.5)		(83.9)		(159.1)		(168.2)
Actuarial Loss		31.3		36.5		63.0		75.5
Prior Service Cost		0.9		0.9		1.8		1.8
Total Net Periodic Benefit Expense	$	17.8	$	33.2	$	36.4	$	68.3
Capitalized Pension Expense	$	5.4	$	9.8	$	11.4	$	21.1
	PBOP				PBOP
Eversource	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015(1)		June 30, 2016		June 30, 2015(1)
Service Cost	$	3.1	$	3.9	$	6.3	$	8.1
Interest Cost		9.4		11.7		19.0		23.6
Expected Return on Plan Assets		(15.7)		(16.9)		(31.5)		(33.7)
Actuarial Loss		0.9		1.7		2.1		3.4
Prior Service Credit		-		(0.2)		(0.1)		(0.2)
Total Net Periodic Benefit Expense/(Income)	$	(2.3)	$	0.2	$	(4.2)	$	1.2
Capitalized PBOP Expense/(Income)	$	(1.0)	$	(0.1)	$	(1.9)	$	-

	Pension and SERP
	For the Three Months Ended June 30, 2016								For the Three Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	4.6	$	3.3	$	2.5	$	0.8	$	6.2	$	3.7	$	3.1	$	1.0
Interest Cost		10.2		8.5		5.1		2.1		12.9		10.0		6.1		2.6
Expected Return on Plan Assets		(18.0)		(16.9)		(9.6)		(4.4)		(19.8)		(17.5)		(10.1)		(4.7)
Actuarial Loss		6.3		8.7		2.6		1.3		8.0		8.7		2.9		1.6
Prior Service Cost		0.4		-		0.1		0.1		0.4		-		0.1		0.1
Total Net Periodic Benefit Expense/(Income)	$	3.5	$	3.6	$	0.7	$	(0.1)	$	7.7	$	4.9	$	2.1	$	0.6
Intercompany Allocations	$	3.5	$	2.2	$	1.0	$	0.6	$	5.8	$	3.4	$	1.6	$	1.1
Capitalized Pension Expense	$	2.2	$	2.0	$	0.4	$	0.1	$	4.7	$	2.7	$	0.9	$	0.5
	Pension and SERP
	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	9.6	$	6.7	$	5.0	$	1.6	$	12.2	$	7.5	$	6.0	$	2.2
Interest Cost		21.0		16.8		10.3		4.2		25.4		20.1		12.1		5.2
Expected Return on Plan Assets		(36.2)		(33.8)		(19.3)		(8.8)		(39.4)		(35.1)		(20.2)		(9.4)
Actuarial Loss		13.0		17.0		4.9		2.8		16.2		18.4		5.8		3.2
Prior Service Cost		0.8		-		0.2		0.2		0.8		-		0.2		0.1
Total Net Periodic Benefit Expense	$	8.2	$	6.7	$	1.1	$	-	$	15.2	$	10.9	$	3.9	$	1.3
Intercompany Allocations	$	6.8	$	4.5	$	2.0	$	1.2	$	12.2	$	6.9	$	3.4	$	2.3
Capitalized Pension Expense	$	4.9	$	3.7	$	0.7	$	0.2	$	9.4	$	5.9	$	1.7	$	1.0

	PBOP
	For the Three Months Ended June 30, 2016								For the Three Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	0.4	$	1.0	$	0.3	$	0.1	$	0.5	$	1.3	$	0.3	$	0.1
Interest Cost		1.3		3.8		0.7		0.3		1.8		4.7		1.0		0.3
Expected Return on Plan Assets		(2.5)		(6.4)		(1.4)		(0.6)		(2.8)		(6.9)		(1.5)		(0.6)
Actuarial Loss		0.3		0.3		0.1		0.0		0.2		0.4		0.1		-
Prior Service Credit		-		-		-		-		-		(0.1)		-		-
Total Net Periodic Benefit Income	$	(0.5)	$	(1.3)	$	(0.3)	$	(0.2)	$	(0.3)	$	(0.6)	$	(0.1)	$	(0.2)
Intercompany Allocations	$	0.2	$	0.1	$	-	$	0.0	$	0.4	$	0.2	$	0.1	$	0.1
Capitalized PBOP Income	$	(0.2)	$	(0.6)	$	(0.1)	$	(0.1)	$	(0.1)	$	(0.2)	$	-	$	-
	PBOP
	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
			NSTAR									NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH		WMECO	CL&P			Electric	PSNH (1)		WMECO
Service Cost	$	0.9	$	1.8	$	0.6	$	0.2	$	1.1	$	2.7	$	0.7	$	0.2
Interest Cost		2.7		7.8		1.5		0.5		3.5		9.5		1.9		0.8
Expected Return on Plan Assets		(5.1)		(12.7)		(2.8)		(1.1)		(5.5)		(13.7)		(3.0)		(1.3)
Actuarial Loss		0.5		0.5		0.2		0.0		0.3		1.2		0.3		-
Prior Service Credit		-		-		-		-		-		(0.1)		-		-
Total Net Periodic Benefit Income	$	(1.0)	$	(2.6)	$	(0.5)	$	(0.4)	$	(0.6)	$	(0.4)	$	(0.1)	$	(0.3)
Intercompany Allocations	$	0.3	$	0.1	$	-	$	0.1	$	0.9	$	0.4	$	0.2	$	0.2
Capitalized PBOP Expense/(Income)	$	(0.5)	$	(1.1)	$	(0.1)	$	(0.2)	$	(0.1)	$	(0.1)	$	0.1	$	(0.1)
(1) Amounts excluded approximately $0.8 million and $1.6 million for the three and six months ended June 30, 2015, respectively, that represented amounts included in other deferred debits.

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Commitments and Contingencies Disclosure [Text Block]

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 ofenvironmental 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 June 30, 2016				As of December 31, 2015
			Reserve				Reserve
	Number of Sites		(in millions)		Number of Sites		(in millions)
Eversource		63	$	59.5		64	$	51.1
CL&P		14		4.6		14		4.6
NSTAR Electric		14		2.3		15		2.4
PSNH		12		4.4		12		4.5
WMECO		4		0.6		4		0.6

Included in the Eversourcenumber 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 $53.7million and $45.5million as of June 30, 2016 and December31, 2015, respectively, and related primarily to the natural gas business segment.

These reserve estimates are subjective in nature as they take into consideration several different remediation options at each specific site. The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource's, CL&P's, NSTAR Electric's, PSNH's, and WMECO's responsibility for remediation or the extent of remediation required, recently enacted laws and regulations or changes in cost estimates due to certain economic factors. It is possible that new information or future developments could require a reassessment of the potential exposure to related environmental matters. As this information becomes available, management will continue to assess the potential exposure and adjust the reserves accordingly.

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 a wholly-owned subsidiary to guarantee the payment of the 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 obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations.Eversource parent has also entered into a guaranty on behalf of NPT under which Eversource parent will guarantee NPT's obligations under its letter of credit 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 as a result of these various guarantees and indemnifications.

The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiariesto external parties, as of June 30, 2016:

			Maximum Exposure
Company		Description	(in millions)		Expiration Dates
On behalf of subsidiaries:
	Eversource Gas Transmission LLC	Access Northeast Project Capital Contributions Guaranty	$	187.4	2021
	Various	Surety Bonds (1)	$	35.8	2016 - 2018
	Eversource Service and Rocky River Realty Company	Lease Payments for Vehicles and Real Estate	$	10.1	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 Eversourceparentare 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'sfailure to provide for a permanent facility to store spent nuclear fuelpursuant 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, awarding 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 by the Yankee Companies in Phase III. The decision became final on July 18, 2016. Management cannot predict the timing or amount of any customer refunds. At this time, the proceeds are primarily expected to be used by the Yankee Companies to fund remaining fuel storage obligations, and management does not expect any significant amounts to be refunded to Eversource utilities (CL&P,NSTAR Electric, PSNH and WMECO). The utilities would then ultimately refundany amounts received to utility customers.

D.       FERC ROE Complaints

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

As a result of developments in this matter, the Company recorded reserves across the complaint periods at its electric subsidiaries in the first halfof 2015 and recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO. The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues. The NETOs and Complainants have filed appeals for the first complaint to the D.C. Circuit Court of Appeals. A court decision is expected in late 2016.

For the second and third complaints, the state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced to an amount lower than 10.57 percent. The NETOs believe that the Complainants' positions are without merit. On March 22, 2016, the FERC ALJ issued an initial decision on the second and third FERC ROE 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 Company believes that the range of potential loss 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, the Company concluded there is currently no range of potential loss for that complaint period. 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 outcome of the final FERC order on these 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.

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.

FERC ROE Complaint IV:On April 29, 2016, a fourth complaint was filed with the FERC by certain municipal utilities claiming 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. At this time FERC has not taken any action with respect to this complaint; therefore the Company is unable to predict the outcome of this complaint.

E.       PSNH Generation Restructuring

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

On July 1, 2016, the NHPUC approved the Agreement in an order that, among other things, instructs PSNH to begin the process to divest its generation assets. The NHPUC is in the process of selecting an auction adviser to assist with the divestiture. 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.

If the NHPUC approves the sale of the plants, the Company expects the plants will be sold prior to the end of 2017. The sales price of the generating assets could be less than the carrying value, but the Company believes that full recovery of PSNH's generation assets is probable through a combination of cash flows during the remaining operating period, sales proceeds upon divestiture, and recovery of stranded costs in future rates.

F.       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”), and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the “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' 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 it has valid defenses to the claims and intends to defend it 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 and NSTAR Electric's financial position, results of operations, or cash flows.

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FAIR VALUE OF FINANCIAL INSTRUMENTS

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Fair Value Disclosures [Text Block]

9.       FAIR VALUE OF FINANCIAL INSTRUMENTS

The following methods and assumptions were used to estimate the fair value of each of the following financial instruments:

Preferred Stock and Long-Term Debt: The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections. The fair value of long-term debt securities is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields. The fair values provided in the tables below are classified as Level 2 within the fair value hierarchy. Carrying amounts and estimated fair values are as follows:

	As of June 30, 2016				As of December 31, 2015
Eversource	Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	157.5	$	155.6	$	157.9
Long-Term Debt		9,614.8		10,512.0		9,034.5		9,425.9

	CL&P				NSTAR Electric				PSNH				WMECO
	Carrying		Fair		Carrying		Fair		Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value		Amount		Value		Amount		Value
As of June 30, 2016:
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	115.0	$	43.0	$	42.5	$	-	$	-	$	-	$	-
Long-Term Debt		2,764.9		3,240.4		2,077.7		2,354.3		1,071.5		1,150.8		566.9		617.3
As of December 31, 2015:
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	114.9	$	43.0	$	43.0	$	-	$	-	$	-	$	-
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

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

Marketable Securities: Investments in marketable securities are carried at fair value. For further information, see Note 5, "Marketable Securities," to the financial statements.

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

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ACCUMULATED OTHER COMPREHENSIVE INCOME

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Comprehensive Income Note [Text Block]

10.       ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

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

	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
	Qualified		Unrealized						Qualified		Unrealized
	Cash Flow		Gains/(Losses)		Defined				Cash Flow		Gains/(Losses)		Defined
Eversource	Hedging		on Marketable		Benefit				Hedging		on Marketable		Benefit
(Millions of Dollars)	Instruments		Securities		Plans		Total		Instruments		Securities		Plans		Total
Balance as of Beginning of Period	$	(10.3)	$	(1.9)	$	(54.6)	$	(66.8)	$	(12.4)	$	0.7	$	(62.3)	$	(74.0)
OCI Before Reclassifications		-		1.3		(2.6)		(1.3)		-		(1.1)		(0.4)		(1.5)
Amounts Reclassified from AOCI		1.1		-		1.6		2.7		1.0		-		2.5		3.5
Net OCI		1.1		1.3		(1.0)		1.4		1.0		(1.1)		2.1		2.0
Balance as of End of Period	$	(9.2)	$	(0.6)	$	(55.6)	$	(65.4)	$	(11.4)	$	(0.4)	$	(60.2)	$	(72.0)

Eversource's qualified cash flow hedging instruments represent interest rate swap agreements on debt issuances that were settled in prior years. The settlement amount was recorded in AOCI and is being amortized into Net Income over the term of the underlying debt instrument.CL&P, PSNH and WMECO continue to amortize interest rate swaps settled in prior years from AOCI into Interest Expense over the remaining life of the associated long-term debt. Such interest rate swaps are not material to their respective financial statements.

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses that arose during the year and were recognized in AOCI.

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

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COMMON SHARES

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule of Stock by Class [Text Block]

11.       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
			Authorized as of
	Per Share		June 30, 2016 and	Issued as of
	Par Value		December 31, 2015	June 30, 2016	December 31, 2015
Eversource	$	5	380,000,000	333,878,402	333,862,615
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	100	100
PSNH	$	1	100,000,000	301	301
WMECO	$	25	1,072,471	434,653	434,653

As of both June 30, 2016 and December31, 2015, there were 16,671,366Eversource common shares held as treasury shares. As of June 30, 2016 and December31, 2015, Eversource common shares outstanding were 317,207,036 and 317,191,249, respectively.

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COMMON SHARESHOLDERS' EQUITY AND NONCONTROLLING INTERESTS (NU)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Stockholders' Equity Note Disclosure [Text Block]

12.       COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for the three months ended June 30, 2016 and 2015, and $3.8 million for the six months ended June 30, 2016 and 2015. These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of June 30, 2016 and December 31, 2015. Common Shareholders' Equity was fully attributable to the parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrollinginterest on the Eversource balance sheets.

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EARNINGS PER SHARE

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Earnings Per Share [Text Block]

13.       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 awardsas 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 six months ended June 30, 2016 and 2015, there were no antidilutive share awards excluded from the computation.

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

Eversource		For the Three Months Ended				For the Six Months Ended
(Millions of Dollars, except share information)		June 30, 2016		June 30, 2015		June 30, 2016		June 30, 2015
Net Income Attributable to Common Shareholders		$	203.6	$	207.5	$	447.8	$	460.8
Weighted Average Common Shares Outstanding:
	Basic		317,785,495		317,613,166		317,651,319		317,352,004
	Dilutive Effect		691,204		946,402		827,557		1,173,374
	Diluted		318,476,699		318,559,568		318,478,876		318,525,378
Basic and Diluted EPS		$	0.64	$	0.65	$	1.41	$	1.45

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SEGMENT INFORMATION

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Segment Reporting Disclosure [Text Block]

14.SEGMENT INFORMATION

Presentation:Eversource is organized into 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' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates. These reportable segments represent substantially all of Eversource's total consolidated revenues. Revenues from the sale of electricity and natural gas primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer. The Electric Distributionreportable segment includes the generation activities of PSNH and WMECO.

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

Cash flows used for investments in plant included in the segment information below are cash capital expenditures that do not include amounts incurred but not paid, cost of removal, AFUDC related to equity funds, andthe capitalized portions of pension expense.

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

Eversource's segment information is as follows:

Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
For the Three Months Ended June 30, 2016:
Operating Revenues	$	1,303.1	$	180.4	$	302.5	$	211.1	$	(229.9)	$	1,767.2
Depreciation and Amortization		(98.4)		(16.8)		(45.6)		(7.5)		0.5		(167.8)
Other Operating Expenses		(994.4)		(141.1)		(82.5)		(188.1)		230.1		(1,176.0)
Operating Income		210.3		22.5		174.4		15.5		0.7		423.4
Interest Expense		(47.6)		(10.4)		(27.4)		(16.6)		1.5		(100.5)
Other Income, Net		6.3		0.1		5.3		219.0		(222.6)		8.1
Net Income Attributable to Common Shareholders	$	102.8	$	8.0	$	92.5	$	220.7	$	(220.4)	$	203.6
For the Six Months Ended June 30, 2016:
Operating Revenues	$	2,739.2	$	523.0	$	585.8	$	425.3	$	(450.5)	$	3,822.8
Depreciation and Amortization		(226.1)		(32.7)		(90.7)		(14.4)		1.1		(362.8)
Other Operating Expenses		(2,083.3)		(374.5)		(155.5)		(385.4)		450.7		(2,548.0)
Operating Income		429.8		115.8		339.6		25.5		1.3		912.0
Interest Expense		(95.6)		(20.5)		(55.3)		(30.7)		3.4		(198.7)
Other Income/(Loss), Net		6.3		(0.2)		7.9		524.4		(528.4)		10.0
Net Income Attributable to Common Shareholders	$	211.3	$	58.9	$	178.2	$	523.1	$	(523.7)	$	447.8
Cash Flows Used for Investments in Plant	$	362.0	$	105.0	$	349.1	$	53.1	$	-	$	869.2

Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
For the Three Months Ended June 30, 2015:
Operating Revenues	$	1,382.7	$	186.0	$	267.8	$	203.7	$	(223.1)	$	1,817.1
Depreciation and Amortization		(98.5)		(17.7)		(39.7)		(7.1)		0.5		(162.5)
Other Operating Expenses		(1,052.1)		(150.2)		(73.1)		(190.7)		223.5		(1,242.6)
Operating Income		232.1		18.1		155.0		5.9		0.9		412.0
Interest Expense		(45.6)		(9.1)		(26.3)		(12.4)		1.1		(92.3)
Other Income, Net		5.5		0.3		5.1		220.1		(218.1)		12.9
Net Income Attributable to Common Shareholders	$	120.9	$	5.3	$	80.4	$	217.0	$	(216.1)	$	207.5
For the Six Months Ended June 30, 2015:
Operating Revenues	$	3,142.8	$	693.4	$	516.8	$	443.7	$	(466.2)	$	4,330.5
Depreciation and Amortization		(257.6)		(35.9)		(80.1)		(14.3)		1.0		(386.9)
Other Operating Expenses		(2,395.0)		(538.7)		(147.2)		(419.9)		466.7		(3,034.1)
Operating Income		490.2		118.8		289.5		9.5		1.5		909.5
Interest Expense		(93.2)		(18.1)		(53.9)		(24.1)		2.2		(187.1)
Other Income, Net		7.6		0.1		8.1		535.0		(532.2)		18.6
Net Income Attributable to Common Shareholders	$	251.4	$	61.0	$	147.0	$	529.9	$	(528.5)	$	460.8
Cash Flows Used for Investments in Plant	$	319.8	$	67.5	$	328.7	$	24.4	$	-	$	740.4
The following table summarizes Eversource's segmented total assets:
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
As of June 30, 2016	$	17,855.6	$	3,122.5	$	8,376.2	$	13,218.3	$	(11,689.9)	$	30,882.7
As of December 31, 2015		17,981.3		3,104.5		8,019.3		13,256.7		(11,781.5)		30,580.3

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SIGNIFCANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Organization Consolidation And Presentation Of Financial Statements Disclosure Text Block

A.       Basis of Presentation

EversourceEnergy is a public utility holding company primarily engaged, through its wholly owned regulated utility subsidiaries, in the energy delivery business.Eversource Energy's wholly owned regulated utility subsidiaries consist of CL&P, NSTAR Electric, PSNH, WMECO, Yankee Gas and NSTAR Gas.Eversource provides energy delivery service to approximately 3.6 million electric and natural gas customers through these six regulated utilities in Connecticut, Massachusetts and New Hampshire.

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 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 Statements and Supplementary Data," of the Eversource 2015 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, CL&P's, NSTAR Electric's, PSNH's and WMECO's financial position as of June 30, 2016 and December31, 2015, the results of operations andcomprehensive incomefor the three and six months ended June 30, 2016 and 2015, and the cash flows for the six months ended June 30, 2016 and 2015. The results of operations andcomprehensive incomefor the three and six months ended June 30, 2016 and 2015 and the cash flows for the six months ended June 30, 2016 and 2015 are not necessarily indicative of the results expected for a full year.

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

Access Northeast is a natural gas pipeline and storage project (the "Project") being developed jointly by Eversource, Spectra Energy Corp and National Grid. Access Northeast will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes. Eversource and Spectra Energy Corp each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid. The total projected cost for both the pipeline and the LNG storage is expected to be approximately $3 billion, to be funded in proportion to ownership interest (approximately $1.2 billion by Eversource), with anticipated in-service dates commencing in November 2018. Eversource's cumulative equity investment in the Project as of June 30, 2016 of $20.7 millionis presented in Other Long-Term Assets.

Eversource's utility subsidiaries' distribution (including generation) and transmission businesses are subject to rate-regulation that is based on cost recovery and meets the criteria for application of accounting guidance for entities with rate-regulated operations, which considers the effect of regulation on the differences in the timing of the recognition of certain revenues and expenses from those of other businesses and industries. See Note2, "Regulatory Accounting," for further information.

Certain reclassifications of prior period data were made in the accompanyingfinancial statements to conform to the current period presentationand as a result of the adoption of new accounting guidance. See Note 1B,"Summary of Significant Accounting Policies – Accounting Standards," for further information.

Receivables Policy Text Block

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

Fair Value Of Financial Instruments Policy

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases or normal sales" (normal) and to the marketable securities held in trusts. Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill and AROs, and the estimated fair value of preferred stock and long-term debt.

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

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

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

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

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

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

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

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.

The following methods and assumptions were used to estimate the fair value of each of the following financial instruments:

Preferred Stock and Long-Term Debt: The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections. The fair value of long-term debt securities is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields. The fair values provided in the tables below are classified as Level 2 within the fair value hierarchy.

Other Taxes Policy

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

Public Utilities Policy Text Block

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

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

Marketable Securities Policy

.Dividend income is recorded in Other Income, Net when dividends are declared.

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 six months ended June 30, 2016 and 2015. Factors considered in determining whether a credit loss exists include the duration and severity of the impairment, adverse conditions specifically affecting the issuer, and the payment history, ratings and rating changes of the security. For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated.

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

Environmental Costs Policy

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.

Earnings Per Share Policy Text Block

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 awardsas 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.

Segment Reporting Policy Policy Text Block

SEGMENT INFORMATION

Presentation:Eversource is organized into 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' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates. These reportable segments represent substantially all of Eversource's total consolidated revenues. Revenues from the sale of electricity and natural gas primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer. The Electric Distributionreportable segment includes the generation activities of PSNH and WMECO.

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

Cash flows used for investments in plant included in the segment information below are cash capital expenditures that do not include amounts incurred but not paid, cost of removal, AFUDC related to equity funds, andthe capitalized portions of pension expense.

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Provision for Uncollectible Accounts (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Accounts Notes Loans And Financing Receivable Text Block

	Total Provision for Uncollectible Accounts				Uncollectible Hardship
(Millions of Dollars)	As of June 30, 2016		As of December 31, 2015		As of June 30, 2016		As of December 31, 2015
Eversource	$	205.5	$	190.7	$	123.7	$	118.5
CL&P		82.7		79.5		66.2		68.1
NSTAR Electric		56.9		52.6		28.6		25.3
PSNH		9.6		8.7		-		-
WMECO		15.3		14.0		8.4		7.4

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Other Taxes (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

State Of Connecticut Gross Earnings Taxes [Table Text Block]

	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015		June 30, 2016		June 30, 2015
Eversource	$	37.5	$	33.2	$	79.8	$	75.1
CL&P		33.6		29.5		69.6		62.5

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Supplemental Cash Flow Information (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule of Cash Flow, Supplemental Disclosures [Table Text Block]

G.	Supplemental Cash Flow Information
Non-cash investing activities include plant additions included in Accounts Payable as follows:
(Millions of Dollars)		As of June 30, 2016		As of June 30, 2015
Eversource		$	186.3	$	142.3
CL&P			59.5		47.2
NSTAR Electric			38.5		29.5
PSNH			31.1		25.6
WMECO			14.6		13.7

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REGULATORY ACCOUNTING (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Regulatory Assets Text Block

	As of June 30, 2016		As of December 31, 2015
(Millions of Dollars)	Eversource		Eversource
Benefit Costs	$	1,754.1	$	1,828.2
Derivative Liabilities		413.7		388.0
Income Taxes, Net		644.3		650.9
Storm Restoration Costs		428.9		436.9
Goodwill-related		474.6		484.9
Regulatory Tracker Mechanisms		562.5		526.5
Contractual Obligations - Yankee Companies		117.3		134.4
Other Regulatory Assets		129.6		134.0
Total Regulatory Assets		4,525.0		4,583.8
Less: Current Portion		863.4		845.8
Total Long-Term Regulatory Assets	$	3,661.6	$	3,738.0

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Benefit Costs	$	383.2	$	477.0	$	160.0	$	77.9	$	413.6	$	479.9	$	164.2	$	84.9
Derivative Liabilities		411.3		2.4		-		-		380.8		1.3		-		-
Income Taxes, Net		442.5		86.3		28.2		31.0		444.4		85.7		34.5		31.8
Storm Restoration Costs		269.5		117.7		21.7		20.0		271.4		110.9		31.5		23.1
Goodwill-related		-		407.5		-		-		-		416.3		-		-
Regulatory Tracker Mechanisms		96.6		287.0		120.5		41.5		45.1		311.0		101.2		40.1
Other Regulatory Assets		78.0		50.9		31.1		12.1		82.0		56.3		31.5		11.3
Total Regulatory Assets		1,681.1		1,428.8		361.5		182.5		1,637.3		1,461.4		362.9		191.2
Less: Current Portion		312.2		316.7		122.9		57.7		268.3		348.4		105.0		56.2
Total Long-Term Regulatory Assets	$	1,368.9	$	1,112.1	$	238.6	$	124.8	$	1,369.0	$	1,113.0	$	257.9	$	135.0

Schedule Of Regulatory Liabilities Text Block

	As of June 30, 2016		As of December 31, 2015
(Millions of Dollars)	Eversource		Eversource
Cost of Removal	$	448.5	$	437.1
Regulatory Tracker Mechanisms		104.4		99.7
AFUDC - Transmission		65.7		66.1
Other Regulatory Liabilities		28.5		18.5
Total Regulatory Liabilities		647.1		621.4
Less: Current Portion		119.4		107.8
Total Long-Term Regulatory Liabilities	$	527.7	$	513.6

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Cost of Removal	$	30.4	$	261.6	$	46.6	$	4.6	$	24.1	$	257.4	$	47.2	$	2.8
Regulatory Tracker Mechanisms		50.0		6.1		3.2		11.1		56.2		3.3		3.4		12.9
AFUDC - Transmission		50.9		6.0		-		8.8		51.5		5.7		-		8.9
Other Regulatory Liabilities		12.6		1.0		3.5		0.1		4.2		1.3		4.2		0.1
Total Regulatory Liabilities		143.9		274.7		53.3		24.6		136.0		267.7		54.8		24.7
Less: Current Portion		63.3		6.9		6.0		11.3		61.2		3.3		6.9		13.1
Total Long-Term Regulatory Liabilities	$	80.6	$	267.8	$	47.3	$	13.3	$	74.8	$	264.4	$	47.9	$	11.6

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PROPERTY, PLANT AND ACCUMULATED DEPRECIATION (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule of Public Utility Property, Plant, and Equipment [Text Block]

		As of June 30, 2016		As of December 31, 2015
(Millions of Dollars)		Eversource		Eversource
Distribution - Electric		$	13,425.4	$	13,054.8
Distribution - Natural Gas			2,819.9		2,727.2
Transmission - Electric			7,896.3		7,691.9
Generation			1,218.3		1,194.1
Electric and Natural Gas Utility			25,359.9		24,668.0
Other (1)			583.5		558.6
Property, Plant and Equipment, Gross			25,943.4		25,226.6
Less: Accumulated Depreciation
	Electric and Natural Gas Utility		(6,342.9)		(6,141.1)
	Other		(274.5)		(255.6)
Total Accumulated Depreciation			(6,617.4)		(6,396.7)
Property, Plant and Equipment, Net			19,326.0		18,829.9
Construction Work in Progress			1,122.5		1,062.5
Total Property, Plant and Equipment, Net		$	20,448.5	$	19,892.4

	As of June 30, 2016								As of December 31, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Distribution	$	5,471.5	$	5,279.1	$	1,883.8	$	831.0	$	5,377.2	$	5,100.5	$	1,804.8	$	812.3
Transmission		3,691.2		2,205.3		972.0		977.9		3,618.0		2,131.3		928.2		964.9
Generation		-		-		1,182.4		35.9		-		-		1,158.1		36.0
Property, Plant and Equipment, Gross		9,162.7		7,484.4		4,038.2		1,844.8		8,995.2		7,231.8		3,891.1		1,813.2
Less: Accumulated Depreciation		(2,089.2)		(1,962.7)		(1,217.3)		(323.0)		(2,041.9)		(1,886.8)		(1,171.0)		(307.0)
Property, Plant and Equipment, Net		7,073.5		5,521.7		2,820.9		1,521.8		6,953.3		5,345.0		2,720.1		1,506.2
Construction Work in Progress		263.1		267.0		104.4		94.5		203.5		310.5		135.3		69.1
Total Property, Plant and Equipment, Net	$	7,336.6	$	5,788.7	$	2,925.3	$	1,616.3	$	7,156.8	$	5,655.5	$	2,855.4	$	1,575.3

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DERIVATIVE INSTRUMENTS (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Derivative Instruments In Statement Of Financial Position Fair Value Text Block

		As of June 30, 2016						As of December 31, 2015
		Commodity Supply				Net Amount		Commodity Supply				Net Amount
		and Price Risk				Recorded as		and Price Risk					Recorded as
(Millions of Dollars)		Management		Netting (1)		a Derivative		Management		Netting (1)		a Derivative
Current Derivative Assets:
Level 2:
	Eversource	$	3.5	$	-	$	3.5	$	-	$	-	$	-
Level 3:
	Eversource		17.5		(10.8)		6.7		16.7		(10.9)		5.8
	CL&P		16.6		(10.8)		5.8		16.7		(10.9)		5.8
	NSTAR Electric		0.9		-		0.9		-		-		-
Long-Term Derivative Assets:
Level 2:
	Eversource	$	-	$	-	$	-	$	0.1	$	-	$	0.1
Level 3:
	Eversource		70.1		(14.8)		55.3		62.0		(19.3)		42.7
	CL&P		69.9		(14.8)		55.1		60.7		(19.3)		41.4
	NSTAR Electric		0.2		-		0.2		1.3		-		1.3
Current Derivative Liabilities:
Level 2:
	Eversource	$	-	$	-	$	-	$	(5.8)	$	-	$	(5.8)
Level 3:
	Eversource		(93.0)		-		(93.0)		(92.3)		-		(92.3)
	CL&P		(91.6)		-		(91.6)		(91.8)		-		(91.8)
	NSTAR Electric		(1.4)		-		(1.4)		(0.5)		-		(0.5)
Long-Term Derivative Liabilities:
Level 3:
	Eversource	$	(381.6)	$	-	$	(381.6)	$	(337.1)	$	-	$	(337.1)
	CL&P		(380.6)		-		(380.6)		(336.2)		-		(336.2)
	NSTAR Electric		(1.0)		-		(1.0)		(0.9)		-		(0.9)

Rollforward Of Net Derivative Asset Liabilities Valued Using Unobservable Inputs [Table Text Block]

	For the Three Months Ended June 30,
	2016						2015
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(387.7)	$	(385.1)	$	(2.6)	$	(406.8)	$	(403.3)	$	(3.5)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities		(46.6)		(46.8)		0.2		(37.1)		(36.8)		(0.3)
Settlements		21.7		20.6		1.1		21.5		19.9		1.6
Fair Value as of End of Period	$	(412.6)	$	(411.3)	$	(1.3)	$	(422.4)	$	(420.2)	$	(2.2)
	For the Six Months Ended June 30,
	2016						2015
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		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 Losses Included in Regulatory Assets and Liabilities		(76.6)		(72.2)		(4.4)		(49.2)		(48.9)		(0.3)
Settlements		44.9		41.7		3.2		42.2		39.6		2.6
Fair Value as of End of Period	$	(412.6)	$	(411.3)	$	(1.3)	$	(422.4)	$	(420.2)	$	(2.2)

Fairvalueinputsliabilitiesquantitativeinformationtabletextblock

	As of June 30, 2016						As of December 31, 2015
		Range				Period Covered		Range				Period Covered
Capacity Prices:
Eversource	$	5.50	-	13.23	per kW-Month	2017 - 2026	$	10.81	-	15.82	per kW-Month	2016 - 2026
CL&P	$	5.50	-	13.23	per kW-Month	2020 - 2026	$	10.81	-	12.60	per kW-Month	2019 - 2026
NSTAR Electric	$	8.50	-	12.11	per kW-Month	2017 - 2018	$	10.81	-	15.82	per kW-Month	2016 - 2019
Forward Reserve:
Eversource, CL&P	$	2.00			per kW-Month	2016 - 2024	$	2.00			per kW-Month	2016 - 2024
REC Prices:
Eversource, NSTAR Electric	$	38	-	42	per REC	2016 - 2018	$	45	-	51	per REC	2016 - 2018

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MARKETABLE SECURITIES (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Available For Sale Securities Reconciliation [Table TextBlock]

		As of June 30, 2016								As of December 31, 2015
				Pre-Tax		Pre-Tax						Pre-Tax		Pre-Tax
Eversource		Amortized		Unrealized		Unrealized				Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains		Losses		Fair Value		Cost		Gains		Losses		Fair Value
	Debt Securities	$	261.0	$	8.4	$	-	$	269.4	$	256.5	$	4.5	$	(0.6)	$	260.4
	Equity Securities		207.8		58.5		(2.3)		264.0		215.3		59.2		(3.4)		271.1

Investments Classified by Contractual Maturity Date [Table Text Block]

Eversource	Amortized
(Millions of Dollars)	Cost		Fair Value
Less than one year (1)	$	27.2	$	27.2
One to five years		61.6		62.4
Six to ten years		45.4		47.2
Greater than ten years		126.8		132.6
Total Debt Securities	$	261.0	$	269.4

Fair Value Heirarchy [Table Text Block]

Eversource
(Millions of Dollars)		As of June 30, 2016		As of December 31, 2015
Level 1:
	Mutual Funds and Equities	$	274.6	$	285.3
	Money Market Funds		21.1		26.9
Total Level 1		$	295.7	$	312.2
Level 2:
	U.S. Government Issued Debt Securities (Agency and Treasury)	$	70.8	$	46.6
	Corporate Debt Securities		39.5		43.9
	Asset-Backed Debt Securities		18.8		20.0
	Municipal Bonds		109.9		111.4
	Other Fixed Income Securities		9.3		11.6
Total Level 2		$	248.3	$	233.5
Total Marketable Securities		$	544.0	$	545.7

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Pension Benefits and Postretirement Benefits Other Than Pensions (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Net Benefit Costs [Table Text Block]

	Pension and SERP				Pension and SERP
Eversource	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015(1)		June 30, 2016		June 30, 2015(1)
Service Cost	$	18.7	$	22.8	$	37.9	$	45.9
Interest Cost		46.4		56.9		92.8		113.3
Expected Return on Plan Assets		(79.5)		(83.9)		(159.1)		(168.2)
Actuarial Loss		31.3		36.5		63.0		75.5
Prior Service Cost		0.9		0.9		1.8		1.8
Total Net Periodic Benefit Expense	$	17.8	$	33.2	$	36.4	$	68.3
Capitalized Pension Expense	$	5.4	$	9.8	$	11.4	$	21.1
	PBOP				PBOP
Eversource	For the Three Months Ended				For the Six Months Ended
(Millions of Dollars)	June 30, 2016		June 30, 2015(1)		June 30, 2016		June 30, 2015(1)
Service Cost	$	3.1	$	3.9	$	6.3	$	8.1
Interest Cost		9.4		11.7		19.0		23.6
Expected Return on Plan Assets		(15.7)		(16.9)		(31.5)		(33.7)
Actuarial Loss		0.9		1.7		2.1		3.4
Prior Service Credit		-		(0.2)		(0.1)		(0.2)
Total Net Periodic Benefit Expense/(Income)	$	(2.3)	$	0.2	$	(4.2)	$	1.2
Capitalized PBOP Expense/(Income)	$	(1.0)	$	(0.1)	$	(1.9)	$	-

	Pension and SERP
	For the Three Months Ended June 30, 2016								For the Three Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	4.6	$	3.3	$	2.5	$	0.8	$	6.2	$	3.7	$	3.1	$	1.0
Interest Cost		10.2		8.5		5.1		2.1		12.9		10.0		6.1		2.6
Expected Return on Plan Assets		(18.0)		(16.9)		(9.6)		(4.4)		(19.8)		(17.5)		(10.1)		(4.7)
Actuarial Loss		6.3		8.7		2.6		1.3		8.0		8.7		2.9		1.6
Prior Service Cost		0.4		-		0.1		0.1		0.4		-		0.1		0.1
Total Net Periodic Benefit Expense/(Income)	$	3.5	$	3.6	$	0.7	$	(0.1)	$	7.7	$	4.9	$	2.1	$	0.6
Intercompany Allocations	$	3.5	$	2.2	$	1.0	$	0.6	$	5.8	$	3.4	$	1.6	$	1.1
Capitalized Pension Expense	$	2.2	$	2.0	$	0.4	$	0.1	$	4.7	$	2.7	$	0.9	$	0.5
	Pension and SERP
	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	9.6	$	6.7	$	5.0	$	1.6	$	12.2	$	7.5	$	6.0	$	2.2
Interest Cost		21.0		16.8		10.3		4.2		25.4		20.1		12.1		5.2
Expected Return on Plan Assets		(36.2)		(33.8)		(19.3)		(8.8)		(39.4)		(35.1)		(20.2)		(9.4)
Actuarial Loss		13.0		17.0		4.9		2.8		16.2		18.4		5.8		3.2
Prior Service Cost		0.8		-		0.2		0.2		0.8		-		0.2		0.1
Total Net Periodic Benefit Expense	$	8.2	$	6.7	$	1.1	$	-	$	15.2	$	10.9	$	3.9	$	1.3
Intercompany Allocations	$	6.8	$	4.5	$	2.0	$	1.2	$	12.2	$	6.9	$	3.4	$	2.3
Capitalized Pension Expense	$	4.9	$	3.7	$	0.7	$	0.2	$	9.4	$	5.9	$	1.7	$	1.0

	PBOP
	For the Three Months Ended June 30, 2016								For the Three Months Ended June 30, 2015
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH (1)		WMECO
Service Cost	$	0.4	$	1.0	$	0.3	$	0.1	$	0.5	$	1.3	$	0.3	$	0.1
Interest Cost		1.3		3.8		0.7		0.3		1.8		4.7		1.0		0.3
Expected Return on Plan Assets		(2.5)		(6.4)		(1.4)		(0.6)		(2.8)		(6.9)		(1.5)		(0.6)
Actuarial Loss		0.3		0.3		0.1		0.0		0.2		0.4		0.1		-
Prior Service Credit		-		-		-		-		-		(0.1)		-		-
Total Net Periodic Benefit Income	$	(0.5)	$	(1.3)	$	(0.3)	$	(0.2)	$	(0.3)	$	(0.6)	$	(0.1)	$	(0.2)
Intercompany Allocations	$	0.2	$	0.1	$	-	$	0.0	$	0.4	$	0.2	$	0.1	$	0.1
Capitalized PBOP Income	$	(0.2)	$	(0.6)	$	(0.1)	$	(0.1)	$	(0.1)	$	(0.2)	$	-	$	-
	PBOP
	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
			NSTAR									NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH		WMECO	CL&P			Electric	PSNH (1)		WMECO
Service Cost	$	0.9	$	1.8	$	0.6	$	0.2	$	1.1	$	2.7	$	0.7	$	0.2
Interest Cost		2.7		7.8		1.5		0.5		3.5		9.5		1.9		0.8
Expected Return on Plan Assets		(5.1)		(12.7)		(2.8)		(1.1)		(5.5)		(13.7)		(3.0)		(1.3)
Actuarial Loss		0.5		0.5		0.2		0.0		0.3		1.2		0.3		-
Prior Service Credit		-		-		-		-		-		(0.1)		-		-
Total Net Periodic Benefit Income	$	(1.0)	$	(2.6)	$	(0.5)	$	(0.4)	$	(0.6)	$	(0.4)	$	(0.1)	$	(0.3)
Intercompany Allocations	$	0.3	$	0.1	$	-	$	0.1	$	0.9	$	0.4	$	0.2	$	0.2
Capitalized PBOP Expense/(Income)	$	(0.5)	$	(1.1)	$	(0.1)	$	(0.2)	$	(0.1)	$	(0.1)	$	0.1	$	(0.1)
(1) Amounts excluded approximately $0.8 million and $1.6 million for the three and six months ended June 30, 2015, respectively, that represented amounts included in other deferred debits.

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Environmental Matters (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Environmental Loss Contingencies By Site Text Block

	As of June 30, 2016				As of December 31, 2015
			Reserve				Reserve
	Number of Sites		(in millions)		Number of Sites		(in millions)
Eversource		63	$	59.5		64	$	51.1
CL&P		14		4.6		14		4.6
NSTAR Electric		14		2.3		15		2.4
PSNH		12		4.4		12		4.5
WMECO		4		0.6		4		0.6

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Guarantees and Indemnifications (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Guarantee Obligations Text Block

			Maximum Exposure
Company		Description	(in millions)		Expiration Dates
On behalf of subsidiaries:
	Eversource Gas Transmission LLC	Access Northeast Project Capital Contributions Guaranty	$	187.4	2021
	Various	Surety Bonds (1)	$	35.8	2016 - 2018
	Eversource Service and Rocky River Realty Company	Lease Payments for Vehicles and Real Estate	$	10.1	2019 - 2024

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Fair Value By Balance Sheet Grouping Text Block

	As of June 30, 2016				As of December 31, 2015
Eversource	Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	157.5	$	155.6	$	157.9
Long-Term Debt		9,614.8		10,512.0		9,034.5		9,425.9

	CL&P				NSTAR Electric				PSNH				WMECO
	Carrying		Fair		Carrying		Fair		Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value		Amount		Value		Amount		Value
As of June 30, 2016:
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	115.0	$	43.0	$	42.5	$	-	$	-	$	-	$	-
Long-Term Debt		2,764.9		3,240.4		2,077.7		2,354.3		1,071.5		1,150.8		566.9		617.3
As of December 31, 2015:
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	114.9	$	43.0	$	43.0	$	-	$	-	$	-	$	-
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

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ACCUMULATED OTHER COMPREHENSIVE INCOME (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Accumulated Other Comprehensive Income Loss Table Text Block

	For the Six Months Ended June 30, 2016								For the Six Months Ended June 30, 2015
	Qualified		Unrealized						Qualified		Unrealized
	Cash Flow		Gains/(Losses)		Defined				Cash Flow		Gains/(Losses)		Defined
Eversource	Hedging		on Marketable		Benefit				Hedging		on Marketable		Benefit
(Millions of Dollars)	Instruments		Securities		Plans		Total		Instruments		Securities		Plans		Total
Balance as of Beginning of Period	$	(10.3)	$	(1.9)	$	(54.6)	$	(66.8)	$	(12.4)	$	0.7	$	(62.3)	$	(74.0)
OCI Before Reclassifications		-		1.3		(2.6)		(1.3)		-		(1.1)		(0.4)		(1.5)
Amounts Reclassified from AOCI		1.1		-		1.6		2.7		1.0		-		2.5		3.5
Net OCI		1.1		1.3		(1.0)		1.4		1.0		(1.1)		2.1		2.0
Balance as of End of Period	$	(9.2)	$	(0.6)	$	(55.6)	$	(65.4)	$	(11.4)	$	(0.4)	$	(60.2)	$	(72.0)

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COMMON SHARES (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule of Stock by Class [Text Block]

11.       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
			Authorized as of
	Per Share		June 30, 2016 and	Issued as of
	Par Value		December 31, 2015	June 30, 2016	December 31, 2015
Eversource	$	5	380,000,000	333,878,402	333,862,615
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	100	100
PSNH	$	1	100,000,000	301	301
WMECO	$	25	1,072,471	434,653	434,653

As of both June 30, 2016 and December31, 2015, there were 16,671,366Eversource common shares held as treasury shares. As of June 30, 2016 and December31, 2015, Eversource common shares outstanding were 317,207,036 and 317,191,249, respectively.

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EARNINGS PER SHARE (Tables)

6 Months Ended

Jun. 30, 2016

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Earnings Per Share Basic And Diluted [Table Text Block]

Eversource		For the Three Months Ended				For the Six Months Ended
(Millions of Dollars, except share information)		June 30, 2016		June 30, 2015		June 30, 2016		June 30, 2015
Net Income Attributable to Common Shareholders		$	203.6	$	207.5	$	447.8	$	460.8
Weighted Average Common Shares Outstanding:
	Basic		317,785,495		317,613,166		317,651,319		317,352,004
	Dilutive Effect		691,204		946,402		827,557		1,173,374
	Diluted		318,476,699		318,559,568		318,478,876		318,525,378
Basic and Diluted EPS		$	0.64	$	0.65	$	1.41	$	1.45

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SEGMENT INFORMATION (Tables)

6 Months Ended

Jun. 30, 2016

Segment Reporting Information [Line Items]

Schedule Of Segment Reporting Information By Segment Text Block

Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
For the Three Months Ended June 30, 2016:
Operating Revenues	$	1,303.1	$	180.4	$	302.5	$	211.1	$	(229.9)	$	1,767.2
Depreciation and Amortization		(98.4)		(16.8)		(45.6)		(7.5)		0.5		(167.8)
Other Operating Expenses		(994.4)		(141.1)		(82.5)		(188.1)		230.1		(1,176.0)
Operating Income		210.3		22.5		174.4		15.5		0.7		423.4
Interest Expense		(47.6)		(10.4)		(27.4)		(16.6)		1.5		(100.5)
Other Income, Net		6.3		0.1		5.3		219.0		(222.6)		8.1
Net Income Attributable to Common Shareholders	$	102.8	$	8.0	$	92.5	$	220.7	$	(220.4)	$	203.6
For the Six Months Ended June 30, 2016:
Operating Revenues	$	2,739.2	$	523.0	$	585.8	$	425.3	$	(450.5)	$	3,822.8
Depreciation and Amortization		(226.1)		(32.7)		(90.7)		(14.4)		1.1		(362.8)
Other Operating Expenses		(2,083.3)		(374.5)		(155.5)		(385.4)		450.7		(2,548.0)
Operating Income		429.8		115.8		339.6		25.5		1.3		912.0
Interest Expense		(95.6)		(20.5)		(55.3)		(30.7)		3.4		(198.7)
Other Income/(Loss), Net		6.3		(0.2)		7.9		524.4		(528.4)		10.0
Net Income Attributable to Common Shareholders	$	211.3	$	58.9	$	178.2	$	523.1	$	(523.7)	$	447.8
Cash Flows Used for Investments in Plant	$	362.0	$	105.0	$	349.1	$	53.1	$	-	$	869.2

Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
For the Three Months Ended June 30, 2015:
Operating Revenues	$	1,382.7	$	186.0	$	267.8	$	203.7	$	(223.1)	$	1,817.1
Depreciation and Amortization		(98.5)		(17.7)		(39.7)		(7.1)		0.5		(162.5)
Other Operating Expenses		(1,052.1)		(150.2)		(73.1)		(190.7)		223.5		(1,242.6)
Operating Income		232.1		18.1		155.0		5.9		0.9		412.0
Interest Expense		(45.6)		(9.1)		(26.3)		(12.4)		1.1		(92.3)
Other Income, Net		5.5		0.3		5.1		220.1		(218.1)		12.9
Net Income Attributable to Common Shareholders	$	120.9	$	5.3	$	80.4	$	217.0	$	(216.1)	$	207.5
For the Six Months Ended June 30, 2015:
Operating Revenues	$	3,142.8	$	693.4	$	516.8	$	443.7	$	(466.2)	$	4,330.5
Depreciation and Amortization		(257.6)		(35.9)		(80.1)		(14.3)		1.0		(386.9)
Other Operating Expenses		(2,395.0)		(538.7)		(147.2)		(419.9)		466.7		(3,034.1)
Operating Income		490.2		118.8		289.5		9.5		1.5		909.5
Interest Expense		(93.2)		(18.1)		(53.9)		(24.1)		2.2		(187.1)
Other Income, Net		7.6		0.1		8.1		535.0		(532.2)		18.6
Net Income Attributable to Common Shareholders	$	251.4	$	61.0	$	147.0	$	529.9	$	(528.5)	$	460.8
Cash Flows Used for Investments in Plant	$	319.8	$	67.5	$	328.7	$	24.4	$	-	$	740.4
The following table summarizes Eversource's segmented total assets:
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
As of June 30, 2016	$	17,855.6	$	3,122.5	$	8,376.2	$	13,218.3	$	(11,689.9)	$	30,882.7
As of December 31, 2015		17,981.3		3,104.5		8,019.3		13,256.7		(11,781.5)		30,580.3

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Basis of Presentation (Details)	6 Months Ended
	Jun. 30, 2016
Description of Consolidation of Yankee Companies	Eversource consolidates CYAPC and YAEC because CL&P's, NSTAR Electric's, PSNH's and WMECO's combined ownership interest in each of these entities is greater than 50 percent. Intercompany transactions between CL&P, NSTAR Electric, PSNH and WMECO and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements. Access Northeast is a natural gas pipeline and storage project (the "Project") being developed jointly by Eversource, Spectra Energy Corp and National Grid. Access Northeast will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes. Eversource and Spectra Energy Corp each own a 40 percent interest in the Project, with the remaining 20 percent interest owned by National Grid. The total projected cost for both the pipeline and the LNG storage is expected to be approximately $3 billion, to be funded in proportion to ownership interest (approximately $1.2 billion by Eversource), with anticipated in-service dates commencing in November 2018. Eversource’s cumulative equity investment in the Project as of June 30, 2016 of $20.7 million is presented in Other Long-Term Assets.

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ACCOUNTING STANDARDS (Details) - USD ($) $ in Millions	Jun. 30, 2016	Jun. 30, 2015
Available for sale securities subject to new accounting guidance	$ 48.0
Impact of share based compensation accounting guidance on income tax	2.7
Impact of new accounting standard on cash flow statement	$ 9.1	$ 9.7

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Provision for Uncollectible Accounts (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	$ 205.5	$ 190.7
Uncollectible Hardship Accounts Receivable Reserve	123.7	118.5
The Connecticut Light And Power Company [Member]
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	82.7	79.5
Uncollectible Hardship Accounts Receivable Reserve	66.2	68.1
NSTAR Electric Company [Member]
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	56.9	52.6
Uncollectible Hardship Accounts Receivable Reserve	28.6	25.3
Public Service Company Of New Hampshire [Member]
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	9.6	8.7
Western Massachusetts Electric Company [Member]
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	15.3	14.0
Uncollectible Hardship Accounts Receivable Reserve	$ 8.4	$ 7.4

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Other Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Excise And Sales Taxes	$ 37.5	$ 33.2	$ 79.8	$ 75.1
The Connecticut Light And Power Company [Member]
Excise And Sales Taxes	$ 33.6	$ 29.5	$ 69.6	$ 62.5

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Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Capital Expenditures Incurred But Not Yet Paid	$ 186.3	$ 142.3
The Connecticut Light And Power Company [Member]
Capital Expenditures Incurred But Not Yet Paid	59.5	47.2
NSTAR Electric Company [Member]
Capital Expenditures Incurred But Not Yet Paid	38.5	29.5
Public Service Company Of New Hampshire [Member]
Capital Expenditures Incurred But Not Yet Paid	31.1	25.6
Western Massachusetts Electric Company [Member]
Capital Expenditures Incurred But Not Yet Paid	$ 14.6	$ 13.7

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REGULATORY ACCOUNTING (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Regulatory Asset [Line Items]
Regulatory Assets, Total	$ 4,525,000	$ 4,583,800
Regulatory Assets Current	863,360	845,843
Regulatory Assets Long Term	3,661,578	3,737,960
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	$ 83,000	75,300
Public Utilities Disclosure Of Regulatory Matters
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	$ 647,100	621,400
Regulatory Liability Current	119,413	107,759
Regulatory Liabilities Long-Term	527,678	513,595
The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	1,681,100	1,637,300
Regulatory Assets Current	312,160	268,318
Regulatory Assets Long Term	1,368,897	1,369,028
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	2,600	3,100
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	143,900	136,000
Regulatory Liability Current	63,287	61,155
Regulatory Liabilities Long-Term	80,617	74,830
NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	1,428,800	1,461,400
Regulatory Assets Current	316,715	348,408
Regulatory Assets Long Term	1,112,099	1,112,977
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	38,500	35,400
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	274,700	267,700
Regulatory Liability Current	6,923	3,281
Regulatory Liabilities Long-Term	267,809	264,352
Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	361,500	362,900
Regulatory Assets Current	122,879	104,971
Regulatory Assets Long Term	238,612	257,873
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	5,500	4,800
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	53,300	54,800
Regulatory Liability Current	5,986	6,898
Regulatory Liabilities Long-Term	47,283	47,851
Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	182,500	191,200
Regulatory Assets Current	57,660	56,166
Regulatory Assets Long Term	124,804	135,010
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	19,400	16,700
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	24,600	24,700
Regulatory Liability Current	11,256	13,122
Regulatory Liabilities Long-Term	13,280	11,597
Cost Of Removal [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	448,500	437,100
Cost Of Removal [Member] | The Connecticut Light And Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	30,400	24,100
Cost Of Removal [Member] | NSTAR Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	261,600	257,400
Cost Of Removal [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	46,600	47,200
Cost Of Removal [Member] | Western Massachusetts Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	4,600	2,800
Regulatory Tracker Deferrals Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	104,400	99,700
Regulatory Tracker Deferrals Regulatory Liabilities [Member] | The Connecticut Light And Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	50,000	56,200
Regulatory Tracker Deferrals Regulatory Liabilities [Member] | NSTAR Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	6,100	3,300
Regulatory Tracker Deferrals Regulatory Liabilities [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	3,200	3,400
Regulatory Tracker Deferrals Regulatory Liabilities [Member] | Western Massachusetts Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	11,100	12,900
AFUDC Transmission Incentive [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	65,700	66,100
AFUDC Transmission Incentive [Member] | The Connecticut Light And Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	50,900	51,500
AFUDC Transmission Incentive [Member] | NSTAR Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	6,000	5,700
AFUDC Transmission Incentive [Member] | Western Massachusetts Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	8,800	8,900
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	28,500	18,500
Other Regulatory Liabilities [Member] | The Connecticut Light And Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	12,600	4,200
Other Regulatory Liabilities [Member] | NSTAR Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	1,000	1,300
Other Regulatory Liabilities [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	3,500	4,200
Other Regulatory Liabilities [Member] | Western Massachusetts Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	100	100
Benefit Costs [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	1,754,100	1,828,200
Benefit Costs [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	383,200	413,600
Benefit Costs [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	477,000	479,900
Benefit Costs [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	160,000	164,200
Benefit Costs [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	77,900	84,900
Regulatory Assets Offsetting Derivative Liabilities [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	413,700	388,000
Regulatory Assets Offsetting Derivative Liabilities [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	411,300	380,800
Regulatory Assets Offsetting Derivative Liabilities [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	2,400	1,300
Regulatory Assets Offsetting Derivative Liabilities [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	0	0
Regulatory Assets Offsetting Derivative Liabilities [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	0	0
Deferred Income Tax Charges Member
Regulatory Asset [Line Items]
Regulatory Assets, Total	644,300	650,900
Deferred Income Tax Charges Member | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	442,500	444,400
Deferred Income Tax Charges Member | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	86,300	85,700
Deferred Income Tax Charges Member | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	28,200	34,500
Deferred Income Tax Charges Member | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	31,000	31,800
Storm Restoration Costs [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	428,900	436,900
Storm Restoration Costs [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	269,500	271,400
Storm Restoration Costs [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	117,700	110,900
Storm Restoration Costs [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	21,700	31,500
Storm Restoration Costs [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	20,000	23,100
Goodwill Regulatory Asset [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	474,600	484,900
Goodwill Regulatory Asset [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	407,500	416,300
Regulatory Tracker Deferrals Regulatory Assets [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	562,500	526,500
Regulatory Tracker Deferrals Regulatory Assets [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	96,600	45,100
Regulatory Tracker Deferrals Regulatory Assets [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	287,000	311,000
Regulatory Tracker Deferrals Regulatory Assets [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	120,500	101,200
Regulatory Tracker Deferrals Regulatory Assets [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	41,500	40,100
Unrecovered Contractual Obligations [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	117,300	134,400
Other Regulatory Assets [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	129,600	134,000
Other Regulatory Assets [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	78,000	82,000
Other Regulatory Assets [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	50,900	56,300
Other Regulatory Assets [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	31,100	31,500
Other Regulatory Assets [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	$ 12,100	$ 11,300

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PROPERTY, PLANT AND ACCUMULATED DEPRECIATION (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	$ 13,425,400	$ 13,054,800
Public Utilities Property Plant And Equipment Distribution Natural Gas	2,819,900	2,727,200
Public Utilities Property Plant And Equipment Transmission	7,896,300	7,691,900
Public Utilities Property Plant And Equipment Generation Or Processing	1,218,300	1,194,100
Public Utilities Property Plant And Equipment Electric And Natural Gas Utility Total	25,359,900	24,668,000
Public Utilities Property Plant And Equipment Other Property Plant And Equipment	583,500	558,600
Public Utilities Property Plant And Equipment Plant In Service	25,943,400	25,226,600
Less Accumulated Depreciation [Abstract]
Electric And Natural Gas Utility Accumulated Depreciation	(6,342,900)	(6,141,100)
Other Accumulated Depreciation	(274,500)	(255,600)
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(6,617,400)	(6,396,700)
Property Plant And Equipment Net Excluding Construction Work In Progress	19,326,000	18,829,900
Public Utilities Property Plant And Equipment Construction Work In Progress	1,122,500	1,062,500
Property, Plant and Equipment, Net	20,448,475	19,892,441
The Connecticut Light And Power Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	5,471,500	5,377,200
Public Utilities Property Plant And Equipment Transmission	3,691,200	3,618,000
Public Utilities Property Plant And Equipment Generation Or Processing	0	0
Public Utilities Property Plant And Equipment Plant In Service	9,162,700	8,995,200
Less Accumulated Depreciation [Abstract]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(2,089,200)	(2,041,900)
Property Plant And Equipment Net Excluding Construction Work In Progress	7,073,500	6,953,300
Public Utilities Property Plant And Equipment Construction Work In Progress	263,100	203,500
Property, Plant and Equipment, Net	7,336,577	7,156,809
NSTAR Electric Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	5,279,100	5,100,500
Public Utilities Property Plant And Equipment Transmission	2,205,300	2,131,300
Public Utilities Property Plant And Equipment Generation Or Processing	0	0
Public Utilities Property Plant And Equipment Plant In Service	7,484,400	7,231,800
Less Accumulated Depreciation [Abstract]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,962,700)	(1,886,800)
Property Plant And Equipment Net Excluding Construction Work In Progress	5,521,700	5,345,000
Public Utilities Property Plant And Equipment Construction Work In Progress	267,000	310,500
Property, Plant and Equipment, Net	5,788,659	5,655,458
Public Service Company Of New Hampshire [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	1,883,800	1,804,800
Public Utilities Property Plant And Equipment Transmission	972,000	928,200
Public Utilities Property Plant And Equipment Generation Or Processing	1,182,400	1,158,100
Public Utilities Property Plant And Equipment Plant In Service	4,038,200	3,891,100
Less Accumulated Depreciation [Abstract]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,217,300)	(1,171,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	2,820,900	2,720,100
Public Utilities Property Plant And Equipment Construction Work In Progress	104,400	135,300
Property, Plant and Equipment, Net	2,925,288	2,855,363
Public Service Company Of New Hampshire [Member] | Generation Plant [Member]
Less Accumulated Depreciation [Abstract]
Electric And Natural Gas Utility Accumulated Depreciation	(542,800)
Western Massachusetts Electric Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	831,000	812,300
Public Utilities Property Plant And Equipment Transmission	977,900	964,900
Public Utilities Property Plant And Equipment Generation Or Processing	35,900	36,000
Public Utilities Property Plant And Equipment Plant In Service	1,844,800	1,813,200
Less Accumulated Depreciation [Abstract]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(323,000)	(307,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	1,521,800	1,506,200
Public Utilities Property Plant And Equipment Construction Work In Progress	94,500	69,100
Property, Plant and Equipment, Net	$ 1,616,305	$ 1,575,306

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DERIVATIVE INSTURMENTS (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016 USD ($) $ / KWmo	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($) $ / KWmo	Jun. 30, 2015 USD ($)	Dec. 31, 2015 USD ($) $ / KWmo $ / REC
Derivative Instrument Detail Abstract
Derivative Liabilities, Noncurrent	$ (381,572)		$ (381,572)		$ (337,102)
Other Derivatives Not Designated As Hedging Instruments At Fair Value Net Total Abstract
Description of Derivative Activity Volume			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 June 30, 2016 and December 31, 2015, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately 7.1 million and 9.1 million MMBtu of natural gas, respectively.
Derivative Instruments Not Designated As Hedging Instruments Gain Loss Net Abstract
Derivative Instruments Gain Loss Recognized In Regulatory Asset Liability	(42,900)	$ (36,600)	$ (74,400)	$ (50,100)
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsExitPricePremium			Exit price premiums of 4 percent through 21 percent are also applied on these contracts and reflect the uncertainty and illiquidity premiums that would be required based on the most recent market activity available for similar type contracts
The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(91,603)		$ (91,603)		(91,820)
Derivative Liabilities, Noncurrent	(380,643)		(380,643)		(336,189)
Fair Value Inputs Level 2 [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	6,700		6,700
Fair Value Inputs Level 2 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	3,500		3,500
Derivative Liabilities - Current	0		0		(5,800)
Derivative Assets Noncurrent					100
Fair Value Inputs Level 3 [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current					5,800
Derivative Liabilities - Current	(93,000)		(93,000)		(92,300)
Derivative Liabilities, Noncurrent	(381,600)		(381,600)		(337,100)
Derivative Assets Noncurrent	$ 55,300		$ 55,300		$ 42,700
Fair Value Inputs Level 3 [Member] | Minimum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	5.50		5.50		10.81
FairValueInputsRenewableEnergyCreditPrices | $ / KWmo	38		38		45
FairValueInputsForwardReserve | $ / KWmo	2.00		2.00		2.00
Fair Value Inputs Level 3 [Member] | Maximum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	13.23		13.23		15.82
FairValueInputsRenewableEnergyCreditPrices	42		42		51
FairValueInputsForwardReserve | $ / KWmo
Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	$ 5,800		$ 5,800		$ 5,800
Derivative Liabilities - Current	(91,600)		(91,600)		(91,800)
Derivative Liabilities, Noncurrent	(380,600)		(380,600)		(336,200)
Derivative Assets Noncurrent	$ 55,100		$ 55,100		$ 41,400
Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member] | Minimum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	5.50		5.50		10.81
FairValueInputsForwardReserve | $ / KWmo	2.00		2.00		2.00
Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member] | Maximum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	13.23		13.23		12.60
FairValueInputsForwardReserve | $ / KWmo
Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	$ 900		$ 900
Derivative Liabilities - Current	(1,400)		(1,400)		$ (500)
Derivative Liabilities, Noncurrent	(1,000)		(1,000)		(900)
Derivative Assets Noncurrent	$ 200		$ 200		$ 1,300
Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member] | Minimum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	8.50		8.50		10.81
FairValueInputsRenewableEnergyCreditPrices	38		38		45
Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member] | Maximum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	12.11		12.11		15.82
FairValueInputsRenewableEnergyCreditPrices	42		42		51
Amount Offset Against Derivatives [Member] | Fair Value Inputs Level 2 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	$ 0		$ 0
Amount Offset Against Derivatives [Member] | Fair Value Inputs Level 3 [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	(10,800)		(10,800)		$ (10,900)
Derivative Liabilities - Current	0		0
Derivative Assets Noncurrent	(14,800)		(14,800)		(19,300)
Amount Offset Against Derivatives [Member] | Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	(10,800)		(10,800)		(10,900)
Derivative Assets Noncurrent	(14,800)		(14,800)		(19,300)
Commodity [Member] | Fair Value Inputs Level 2 [Member] | Subsidiaries [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	3,500		3,500
Derivative Liabilities - Current	0		0		(5,800)
Derivative Assets Noncurrent					100
Commodity [Member] | Fair Value Inputs Level 3 [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	17,500		17,500		16,700
Derivative Liabilities - Current	(93,000)		(93,000)		(92,300)
Derivative Liabilities, Noncurrent	(381,600)		(381,600)		(337,100)
Derivative Assets Noncurrent	70,100		70,100		62,000
Commodity [Member] | Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	16,600		16,600		16,700
Derivative Liabilities - Current	(91,600)		(91,600)		(91,800)
Derivative Liabilities, Noncurrent	(380,600)		(380,600)		(336,200)
Derivative Assets Noncurrent	69,900		69,900		60,700
Commodity [Member] | Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	900		900
Derivative Liabilities - Current	(1,400)		(1,400)		(500)
Derivative Liabilities, Noncurrent	(1,000)		(1,000)		(900)
Derivative Assets Noncurrent	$ 200		$ 200		$ 1,300

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Fair Value Measurements (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ (387.7)	$ (406.8)	$ (380.9)	$ (415.4)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	(46.6)	(37.1)	(76.6)	(49.2)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	21.7	21.5	44.9	42.2
Ending Balance	(412.6)	(422.4)	(412.6)	(422.4)
The Connecticut Light And Power Company [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(385.1)	(403.3)	(380.8)	(410.9)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	(46.8)	(36.8)	(72.2)	(48.9)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	20.6	19.9	41.7	39.6
Ending Balance	(411.3)	(420.2)	(411.3)	(420.2)
NSTAR Electric Company [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(2.6)	(3.5)	(0.1)	(4.5)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	0.2	(0.3)	(4.4)	(0.3)
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	1.1	1.6	3.2	2.6
Ending Balance	$ (1.3)	$ (2.2)	$ (1.3)	$ (2.2)

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MARKETABLE SECURITIES (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Investments, Debt and Equity Securities [Abstract]
Marketable Securities, Restricted	$ 439.5		$ 439.5		$ 436.9
Available For Sale Securities Debt Maturities Fair Value Abstract
Available For Sale Securities Debt Maturities After Five Through Ten Years Fair Value	47.2		47.2
Available For Sale Securities Debt Maturities After Ten Years Fair Value	132.6		132.6
Available For Sale Securities Debt Maturities After One Year Through Five Years Fair Value	62.4		62.4
Available For Sale Securities Debt Maturities Within One Year Fair Value	27.2		27.2
Available For Sale Securities Debt Maturities Fair Value	269.4		269.4
Available For Sale Securities Debt Maturities Amortized Cost Abstract
Available For Sale Securities Debt Maturities After One Through Five Years Amortized Cost	61.6		61.6
Available For Sale Securities Debt Maturities Within One Year Amortized Cost	27.2		27.2
Available For Sale Securities Debt Maturities After Ten Years Amortized Cost	126.8		126.8
Available For Sale Securities Debt Maturities After Five Through Ten Years Amortized Cost	45.4		45.4
Available For Sale Securities Debt Maturities Amortized Cost	261.0		261.0
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	544.0		544.0		545.7
TradingSecuritiesEquity	10.6		10.6		14.2
IncreaseDecreaseInTradingSecurities	0.2	$ 0.5	0.5	$ 2.1
Fair Value Inputs Level 1 Member
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	295.7		295.7		312.2
Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	248.3		248.3		233.5
US Government Debt Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	70.8		70.8		46.6
Corporate Bond Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	39.5		39.5		43.9
Asset Backed Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	18.8		18.8		20.0
Municipal Bonds Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	109.9		109.9		111.4
Other Debt Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	9.3		9.3		11.6
Cash And Cash Equivalents Member | Fair Value Inputs Level 1 Member
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	21.1		21.1		26.9
Mutual Funds [Member] | Fair Value Inputs Level 1 Member
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	274.6		274.6		285.3
Debt Securities
Investments, Debt and Equity Securities [Abstract]
Available For Sale Securities Fair Value Disclosure	269.4		269.4		260.4
Available-for-sale Securities, Gross Unrealized Gains			8.4		4.5
AvailableForSaleSecuritiesGrossUnrealizedLoss			0.0		(0.6)
Available For Sale Securities Amortized Cost	261.0		261.0		256.5
Equity Securities
Investments, Debt and Equity Securities [Abstract]
Available For Sale Securities Fair Value Disclosure	264.0		264.0		271.1
Available-for-sale Securities, Gross Unrealized Gains			58.5		59.2
AvailableForSaleSecuritiesGrossUnrealizedLoss			(2.3)		(3.4)
Available For Sale Securities Amortized Cost	$ 207.8		$ 207.8		$ 215.3

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SHORT-TERM DEBT AND LONG-TERM DEBT (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Line of Credit Facility [Line Items]
Line of Credit Facility, Description	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 June 30, 2016 and December 31, 2015, Eversource parent had $438 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $1.0 billion and $351.5 million of available borrowing capacity as of June 30, 2016 and December 31, 2015, respectively. The weighted-average interest rate on these borrowings as of June 30, 2016 and December 31, 2015 was 0.66 percent and 0.72 percent, respectively. As of June 30, 2016, there were intercompany loans from Eversource parent of $93 million to CL&P, $120.9 million to PSNH and $53.7 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 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, which terminates on September 4, 2020. The revolving credit facility serves to backstop Eversource parent's $1.45 billion commercial paper program. 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 June 30, 2016 and December 31, 2015, NSTAR Electric had $329 million and $62.5 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $121 million and $387.5 million of available borrowing capacity as of June 30, 2016 and December 31, 2015, respectively. The weighted-average interest rate on these borrowings as of June 30, 2016 and December 31, 2015 was 0.44 percent and 0.40 percent, respectively. NSTAR Electric is a party to a five-year $450 million revolving credit facility, which terminates on September 4, 2020. The revolving credit facility serves to backstop NSTAR Electric's $450 million commercial paper program.
Notes Payable	$ 767,000	$ 1,160,953
Long-term Debt, Description	Long-Term Debt Issuances: Long-Term Debt Issuances: In March 2016, Eversource parent issued $250 million of 2.50 percent Series I Senior Notes due to mature in 2021 and $250 million of 3.35 percent Series J Senior Notes due to mature in 2026. 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 issued $250 million of 2.70 percent debentures, 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. The proceeds, net of issuance costs, were used to repay short-term borrowings. Long-Term Debt Repayments: In May 2016, NSTAR Electric repaid at maturity $200 million variable rate debentures, using short-term borrowings.
The Connecticut Light And Power Company [Member]
Line of Credit Facility [Line Items]
Notes Payable To Affiliated Companies	$ 93,000	277,400
NSTAR Electric Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	450,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 121,000	$ 388,000
Short-term Debt, Weighted Average Interest Rate	0.44%	0.40%
CommercialPaper	$ 329,000	$ 63,000
Notes Payable	329,000	62,500
Public Service Company Of New Hampshire [Member]
Line of Credit Facility [Line Items]
Notes Payable To Affiliated Companies	120,900	231,300
Western Massachusetts Electric Company [Member]
Line of Credit Facility [Line Items]
Notes Payable To Affiliated Companies	53,700	143,400
Eversource Parent [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity
Line of Credit Facility, Remaining Borrowing Capacity	1,000,000	351,500
Letters Of Credit Outstanding Under Line of Credit	$ 438,000	$ 1,100
Short-term Debt, Weighted Average Interest Rate	0.66%	0.72%

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PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	$ 1,294,548		$ 1,294,548		$ 1,407,288
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Amount That Represents Deferred Regulatory Assets		$ 800		$ 1,600
Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	18,700	22,800	37,900	45,900
Defined Benefit Plan Interest Cost	46,400	56,900	92,800	113,300
Defined Benefit Plan, Expected Return on Plan Assets	(79,500)	(83,900)	(159,100)	(168,200)
Defined Benefit Plan, Amortization of Gains (Losses)	31,300	36,500	63,000	75,500
Defined Benefit Plan Amortization Of Prior Service Cost Credit	900	900	1,800	1,800
Defined Benefit Plan Net Periodic Benefit Cost	17,800	33,200	36,400	68,300
Amount Capitalized Defined Benefit Expense	5,400	9,800	$ 11,400	21,100
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Service Cost Discount Rate Under Spot Rate			4.89%
Interest Cost Discount Rate under spot rate methodology			3.80%
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Impact of Change in Accounting Estimate Spot Rate Discount Rate	11,500		$ 23,000
PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	3,100	3,900	6,300	8,100
Defined Benefit Plan Interest Cost	9,400	11,700	19,000	23,600
Defined Benefit Plan, Expected Return on Plan Assets	(15,700)	(16,900)	(31,500)	(33,700)
Defined Benefit Plan, Amortization of Gains (Losses)	900	1,700	2,100	3,400
Defined Benefit Plan Amortization Of Prior Service Cost Credit	0	(200)	(100)	(200)
Defined Benefit Plan Net Periodic Benefit Cost	(2,300)	200	(4,200)	1,200
Amount Capitalized Defined Benefit Expense	(1,000)	(100)	$ (1,900)	0
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Service Cost Discount Rate Under Spot Rate			5.14%
Interest Cost Discount Rate under spot rate methodology			3.72%
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Impact of Change in Accounting Estimate Spot Rate Discount Rate	2,500		$ 5,000
DefinedBenefitPlanDescriptionOfPlanAmendment			On August 5, 2016, the Company amended its PBOP plan. The amendment standardized separate benefit structures that existed within the plan and made other benefit changes. Overall, the plan amendment is expected to reduce the PBOP plan's accumulated projected benefit obligation by approximately $220 million. The PBOP liability will be remeasured as of August 5, 2016, and the PBOP expense for the remainder of 2016 will be recorded using updated assumptions and actuarial calculations.
DefinedBenefitPlanEffectOfPlanAmendmentOnAccumulatedBenefitObligation	220,000		$ 220,000
The Connecticut Light And Power Company [Member]
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	247,419		247,419		271,056
The Connecticut Light And Power Company [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	4,600	6,200	9,600	12,200
Defined Benefit Plan Interest Cost	10,200	12,900	21,000	25,400
Defined Benefit Plan, Expected Return on Plan Assets	(18,000)	(19,800)	(36,200)	(39,400)
Defined Benefit Plan, Amortization of Gains (Losses)	6,300	8,000	13,000	16,200
Defined Benefit Plan Amortization Of Prior Service Cost Credit	400	400	800	800
Defined Benefit Plan Net Periodic Benefit Cost	3,500	7,700	8,200	15,200
Related Intercompany Allocationsof Defined Benefit Expense	3,500	5,800	6,800	12,200
Amount Capitalized Defined Benefit Expense	2,200	4,700	4,900	9,400
The Connecticut Light And Power Company [Member] | PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	400	500	900	1,100
Defined Benefit Plan Interest Cost	1,300	1,800	2,700	3,500
Defined Benefit Plan, Expected Return on Plan Assets	(2,500)	(2,800)	(5,100)	(5,500)
Defined Benefit Plan, Amortization of Gains (Losses)	300	200	500	300
Defined Benefit Plan Amortization Of Prior Service Cost Credit			0	0
Defined Benefit Plan Net Periodic Benefit Cost	(500)	(300)	(1,000)	(600)
Related Intercompany Allocationsof Defined Benefit Expense	200	400	300	900
Amount Capitalized Defined Benefit Expense	(200)	(100)	(500)	(100)
NSTAR Electric Company [Member]
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	194,734		194,734		209,153
NSTAR Electric Company [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	3,300	3,700	6,700	7,500
Defined Benefit Plan Interest Cost	8,500	10,000	16,800	20,100
Defined Benefit Plan, Expected Return on Plan Assets	(16,900)	(17,500)	(33,800)	(35,100)
Defined Benefit Plan, Amortization of Gains (Losses)	8,700	8,700	17,000	18,400
Defined Benefit Plan Amortization Of Prior Service Cost Credit	0	0	0
Defined Benefit Plan Net Periodic Benefit Cost	3,600	4,900	6,700	10,900
Related Intercompany Allocationsof Defined Benefit Expense	2,200	3,400	4,500	6,900
Amount Capitalized Defined Benefit Expense	2,000	2,700	3,700	5,900
NSTAR Electric Company [Member] | PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	1,000	1,300	1,800	2,700
Defined Benefit Plan Interest Cost	3,800	4,700	7,800	9,500
Defined Benefit Plan, Expected Return on Plan Assets	(6,400)	(6,900)	(12,700)	(13,700)
Defined Benefit Plan, Amortization of Gains (Losses)	300	400	500	1,200
Defined Benefit Plan Amortization Of Prior Service Cost Credit		(100)	0	(100)
Defined Benefit Plan Net Periodic Benefit Cost	(1,300)	(600)	(2,600)	(400)
Related Intercompany Allocationsof Defined Benefit Expense	100	200	100	400
Amount Capitalized Defined Benefit Expense	(600)	(200)	(1,100)	(100)
Public Service Company Of New Hampshire [Member]
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	75,721		75,721		89,579
Public Service Company Of New Hampshire [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	2,500	3,100	5,000	6,000
Defined Benefit Plan Interest Cost	5,100	6,100	10,300	12,100
Defined Benefit Plan, Expected Return on Plan Assets	(9,600)	(10,100)	(19,300)	(20,200)
Defined Benefit Plan, Amortization of Gains (Losses)	2,600	2,900	4,900	5,800
Defined Benefit Plan Amortization Of Prior Service Cost Credit	100	100	200	200
Defined Benefit Plan Net Periodic Benefit Cost	700	2,100	1,100	3,900
Related Intercompany Allocationsof Defined Benefit Expense	1,000	1,600	2,000	3,400
Amount Capitalized Defined Benefit Expense	400	900	700	1,700
Public Service Company Of New Hampshire [Member] | PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	300	300	600	700
Defined Benefit Plan Interest Cost	700	1,000	1,500	1,900
Defined Benefit Plan, Expected Return on Plan Assets	(1,400)	(1,500)	(2,800)	(3,000)
Defined Benefit Plan, Amortization of Gains (Losses)	100	100	200	300
Defined Benefit Plan Amortization Of Prior Service Cost Credit			0	0
Defined Benefit Plan Net Periodic Benefit Cost	(300)	(100)	(500)	(100)
Related Intercompany Allocationsof Defined Benefit Expense		100		200
Amount Capitalized Defined Benefit Expense	(100)	0	(100)	100
Western Massachusetts Electric Company [Member]
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	12,135		12,135		$ 19,515
Western Massachusetts Electric Company [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	800	1,000	1,600	2,200
Defined Benefit Plan Interest Cost	2,100	2,600	4,200	5,200
Defined Benefit Plan, Expected Return on Plan Assets	(4,400)	(4,700)	(8,800)	(9,400)
Defined Benefit Plan, Amortization of Gains (Losses)	1,300	1,600	2,800	3,200
Defined Benefit Plan Amortization Of Prior Service Cost Credit	100	100	200	100
Defined Benefit Plan Net Periodic Benefit Cost	(100)	600	0	1,300
Related Intercompany Allocationsof Defined Benefit Expense	600	1,100	1,200	2,300
Amount Capitalized Defined Benefit Expense	100	500	200	1,000
Western Massachusetts Electric Company [Member] | PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	100	100	200	200
Defined Benefit Plan Interest Cost	300	300	500	800
Defined Benefit Plan, Expected Return on Plan Assets	(600)	(600)	(1,100)	(1,300)
Defined Benefit Plan, Amortization of Gains (Losses)	0	0	0
Defined Benefit Plan Amortization Of Prior Service Cost Credit			0	0
Defined Benefit Plan Net Periodic Benefit Cost	(200)	(200)	(400)	(300)
Related Intercompany Allocationsof Defined Benefit Expense	0	100	100	200
Amount Capitalized Defined Benefit Expense	$ (100)	$ 0	$ (200)	$ (100)

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Environmental Matters (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2016 USD ($)	Dec. 31, 2015 USD ($)
Site Contingency [Line Items]
Environmental Site Quantity	63	64
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 51.1
Ending Balance	59.5	$ 51.1
MGP Site accrual [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	45.5
Ending Balance	$ 53.7	$ 45.5
The Connecticut Light And Power Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	14	14
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 4.6
Ending Balance	$ 4.6	$ 4.6
NSTAR Electric Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	14	15
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 2.4
Ending Balance	$ 2.3	$ 2.4
Public Service Company Of New Hampshire [Member]
Site Contingency [Line Items]
Environmental Site Quantity	12	12
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 4.5
Ending Balance	$ 4.4	$ 4.5
Western Massachusetts Electric Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	4	4
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 0.6
Ending Balance	$ 0.6	$ 0.6

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Guarantees and Indemnifications (Details) $ in Millions	Jun. 30, 2016 USD ($)
Guarantee Of Financial Obligations Of Npt [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	$ 25.0
Various Subsidiary Surety Bonds And Performance Guarantees Expiring Between 2016 And 2018 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	35.8
Guarantee Of Rocky River Reality And Nusco Lease Payments For Real Estate And Vehicles Expiring 2019 Through 2024 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	10.1
Access Northeast Project Capital Contributions Guarantee Expiring In 2021 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	187.4
Guarantee Of Npt Letters Of Credit [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	$ 14.0

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Other Contingencies (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Loss Contingencies [Line Items]
Loss Contingency, Description	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, awarding 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 by the Yankee Companies in Phase III. The decision became final on July 18, 2016. Management cannot predict the timing or amount of any customer refunds. At this time, the proceeds are primarily expected to be used by the Yankee Companies to fund remaining fuel storage obligations, and management does not expect any significant amounts to be refunded to Eversource utilities (CL&P, NSTAR Electric, PSNH and WMECO). The utilities would then ultimately refund any amounts received to utility customers. D.        FERC ROE Complaints FERC ROE Complaints I, II and III: Three separate complaints have been filed at FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively the "Complainants"). In these three separate complaints, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2006 and sought an order to reduce it prospectively from the date of the final FERC order and for the 15-month complaint refund periods stipulated in the separate complaints. In 2014, the FERC ordered a 10.57 percent base ROE for the first complaint refund period and prospectively from October 16, 2014, and that a utility's total or maximum ROE shall not exceed the top of the new zone of reasonableness, which was set at 11.74 percent. In late 2014, the NETOs made a compliance filing, and the Company began issuing refunds to customers from the first complaint period. The Company has refunded all amounts associated with the first complaint period. As a result of developments in this matter, the Company recorded reserves across the complaint periods at its electric subsidiaries in the first half of 2015 and recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO. The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues. The NETOs and Complainants have filed appeals for the first complaint to the D.C. Circuit Court of Appeals. A court decision is expected in late 2016. For the second and third complaints, the state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced to an amount lower than 10.57 percent. The NETOs believe that the Complainants' positions are without merit. On March 22, 2016, the FERC ALJ issued an initial decision on the second and third FERC ROE 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 Company believes that the range of potential loss 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, the Company concluded there is currently no range of potential loss for that complaint period. 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 outcome of the final FERC order on these 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. 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. FERC ROE Complaint IV: On April 29, 2016, a fourth complaint was filed with the FERC by certain municipal utilities claiming 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. At this time FERC has not taken any action with respect to this complaint; therefore the Company is unable to predict the outcome of this complaint. E.        PSNH Generation Restructuring On June 10, 2015, Eversource and PSNH entered into the 2015 Public Service Company of New Hampshire Restructuring and Rate Stabilization Agreement (the Agreement) with the New Hampshire Office of Energy and Planning, certain members of the NHPUC staff, the Office of Consumer Advocate, two State Senators, and several other parties. The Agreement was filed with the NHPUC on the same day. Under the terms of the Agreement, PSNH agreed to divest its generation assets upon NHPUC approval. The Agreement is designed to provide a resolution of issues pertaining to PSNH's generation assets in pending regulatory proceedings before the NHPUC. The Agreement provided for the Clean Air Project prudence proceeding to be resolved and all remaining Clean Air Project costs to be included in rates effective January 1, 2016. As part of the Agreement, PSNH agreed to forego recovery of $25 million of the deferred equity return related to the Clean Air Project. In addition, PSNH will not seek a general distribution rate increase effective before July 1, 2017 and will contribute $5 million to create a clean energy fund, which will not be recoverable from its customers. In 2015, PSNH recorded the $5 million contribution as a long-term liability and an increase to Operations and Maintenance expense on the statements of income. On July 1, 2016, the NHPUC approved the Agreement in an order that, among other things, instructs PSNH to begin the process to divest its generation assets. The NHPUC is in the process of selecting an auction adviser to assist with the divestiture. 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. If the NHPUC approves the sale of the plants, the Company expects the plants will be sold prior to the end of 2017. The sales price of the generating assets could be less than the carrying value, but the Company believes that full recovery of PSNH's generation assets is probable through a combination of cash flows during the remaining operating period, sales proceeds upon divestiture, and recovery of stranded costs in future rates. F.        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”), and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the “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' 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 it has valid defenses to the claims and intends to defend it 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 and NSTAR Electric’s financial position, results of operations, or cash flows.
Public Utilities Disclosure Of Regulatory Matters
FERC ROE Reserve - Cumulative - Pre Tax Charge [Member]
Loss Contingencies [Line Items]
Loss Contingency Loss in Period		$ 20.0
FERC ROE Reserve - Cumulative - Pre Tax Charge [Member] | The Connecticut Light And Power Company [Member]
Loss Contingencies [Line Items]
Loss Contingency Loss in Period		12.5
FERC ROE Reserve - Cumulative - Pre Tax Charge [Member] | NSTAR Electric Company [Member]
Loss Contingencies [Line Items]
Loss Contingency Loss in Period		2.4
FERC ROE Reserve - Cumulative - Pre Tax Charge [Member] | Public Service Company Of New Hampshire [Member]
Loss Contingencies [Line Items]
Loss Contingency Loss in Period		1.0
FERC ROE Reserve - Cumulative - Pre Tax Charge [Member] | Western Massachusetts Electric Company [Member]
Loss Contingencies [Line Items]
Loss Contingency Loss in Period		$ 4.1

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	$ 155,568	$ 155,568
Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	155,600	155,600
Other Long Term Debt	9,614,800	9,034,500
Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	157,500	157,900
Other Long Term Debt	10,512,000	9,425,900
The Connecticut Light And Power Company [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	116,200	116,200
The Connecticut Light And Power Company [Member] | Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	116,200	116,200
Other Long Term Debt	2,764,900	2,763,700
The Connecticut Light And Power Company [Member] | Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	115,000	114,900
Other Long Term Debt	3,240,400	3,031,600
NSTAR Electric Company [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	43,000	43,000
NSTAR Electric Company [Member] | Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	43,000	43,000
Other Long Term Debt	2,077,700	2,029,800
NSTAR Electric Company [Member] | Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	42,500	43,000
Other Long Term Debt	2,354,300	2,182,400
Public Service Company Of New Hampshire [Member] | Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Other Long Term Debt	1,071,500	1,071,000
Public Service Company Of New Hampshire [Member] | Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Other Long Term Debt	1,150,800	1,121,200
Western Massachusetts Electric Company [Member] | Carrying Reported Amount Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Other Long Term Debt	566,900	517,300
Western Massachusetts Electric Company [Member] | Estimate Of Fair Value Fair Value Disclosure [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Other Long Term Debt	$ 617,300	$ 551,800

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ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			$ (66,844)	$ (74,000)
Other Comprehensive Income Before Reclassifications, Net of Tax			(1,300)	(1,500)
Reclassification From OCI, Net Of Tax			2,700	3,500
Other Comprehensive Income (Loss), Net of Tax, Total	$ (189)	$ 381	1,480	1,976
AOCI Ending Balance	(65,364)	(72,000)	(65,364)	(72,000)
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Abstract]
Total Interest Expense	(100,492)	(92,259)	(198,703)	(187,102)
Income Tax Expense	(125,439)	(123,268)	(271,742)	(276,494)
Net Income Attributable to Controlling Interests	203,649	207,507	447,803	460,761
The Connecticut Light And Power Company [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(576)
Other Comprehensive Income (Loss), Net of Tax, Total	147	68	267	183
AOCI Ending Balance	(309)		(309)
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Abstract]
Total Interest Expense	(35,978)	(36,124)	(72,477)	(72,748)
Income Tax Expense	(49,563)	(43,129)	(98,427)	(81,276)
Public Service Company Of New Hampshire [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(6,361)
Other Comprehensive Income (Loss), Net of Tax, Total	354	215	660	514
AOCI Ending Balance	(5,701)		(5,701)
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Abstract]
Total Interest Expense	(12,526)	(11,662)	(24,987)	(22,935)
Income Tax Expense	(19,573)	(15,701)	(41,899)	(35,977)
Western Massachusetts Electric Company [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(2,822)
Other Comprehensive Income (Loss), Net of Tax, Total	120	72	232	158
AOCI Ending Balance	(2,590)		(2,590)
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Abstract]
Total Interest Expense	(6,072)	(6,291)	(12,075)	(13,112)
Income Tax Expense	(9,995)	(9,693)	(20,071)	(18,807)
Qualified Cash Flow Hedging Instruments [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(10,300)	(12,400)
Reclassification From OCI, Net Of Tax			1,100	1,000
Other Comprehensive Income (Loss), Net of Tax, Total			1,100	1,000
AOCI Ending Balance	(9,200)	(11,400)	(9,200)	(11,400)
Unrealized Gains Losses on Available for Sale Securities [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(1,900)	700
Other Comprehensive Income Before Reclassifications, Net of Tax			1,300	(1,100)
Other Comprehensive Income (Loss), Net of Tax, Total			1,300	(1,100)
AOCI Ending Balance	(600)	(400)	(600)	(400)
Pension, SERP and PBOP Benefit Plans [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(54,600)	(62,300)
Other Comprehensive Income Before Reclassifications, Net of Tax			(2,600)	(400)
Reclassification From OCI, Net Of Tax			1,600	2,500
Other Comprehensive Income (Loss), Net of Tax, Total			(1,000)	2,100
AOCI Ending Balance	$ (55,600)	$ (60,200)	$ (55,600)	$ (60,200)

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COMMON SHARES (Details) - $ / shares	Jun. 30, 2016	Dec. 31, 2015
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share	$ 5	$ 5
Common Stock Shares Authorized	380,000,000	380,000,000
Common Stock Shares Issued	333,878,402	333,862,615
Treasury Stock Shares	16,671,366	16,671,366
Common Stock, Shares, Outstanding	317,207,036	317,191,249
The Connecticut Light And Power Company [Member]
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share	$ 10	$ 10
Common Stock Shares Authorized	24,500,000	24,500,000
Common Stock Shares Issued	6,035,205	6,035,205
NSTAR Electric Company [Member]
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share	$ 1	$ 1
Common Stock Shares Authorized	100,000,000	100,000,000
Common Stock Shares Issued	100	100
Public Service Company Of New Hampshire [Member]
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share	$ 1	$ 1
Common Stock Shares Authorized	100,000,000	100,000,000
Common Stock Shares Issued	301	301
Western Massachusetts Electric Company [Member]
Class Of Stock [Line Items]
Common Stock Par Or Stated Value Per Share	$ 25	$ 25
Common Stock Shares Authorized	1,072,471	1,072,471
Common Stock Shares Issued	434,653	434,653

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COMMON SHAREHOLDER EQUIT AND NCI (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Net Income Attributable to Noncontrolling Interests	$ 1,880	$ 1,880	$ 3,759	$ 3,759
Other Comprehensive Income (Loss), Net of Tax	(189)	$ 381	1,480	$ 1,976
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	$ 155,568		$ 155,568		$ 155,568

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EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Notes To Consolidated Financial Statements [Abstract]
Net Income Attributable to Controlling Interests	$ 203,649	$ 207,507	$ 447,803	$ 460,761
Basic	317,785,495	317,613,166	317,651,319	317,352,004
Weighted Average Number Diluted Shares Outstanding Adjustment	691,204	946,402	827,557	1,173,374
Diluted	318,476,699	318,559,568	318,478,876	318,525,378
Earnings Per Share Basic And Diluted	$ 0.64	$ 0.65	$ 1.41	$ 1.45

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SEGMENT INFORMATION (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Segment Reporting Information [Line Items]
Operating Revenues	$ 1,767,184	$ 1,817,061	$ 3,822,819	$ 4,330,491
Operating Income	423,422	412,015	911,958	909,490
Total Interest Expense	(100,492)	(92,259)	(198,703)	(187,102)
Other Income/(Loss), Net	8,038	12,899	10,049	18,626
Income Tax Expense	(125,439)	(123,268)	(271,742)	(276,494)
Net Income	205,529	209,387	451,562	464,520
Net Income Attributable to Noncontrolling Interests	(1,880)	(1,880)	(3,759)	(3,759)
Net Income Attributable to Controlling Interests	203,649	207,507	447,803	460,761
Total Assets	30,882,663		30,882,663		$ 30,580,309
Investments in Property, Plant and Equipment			869,168	740,379
Electric Distribution Member
Segment Reporting Information [Line Items]
Operating Revenues	1,303,100	1,382,700	2,739,200	3,142,800
Depreciation And Amortization	(98,400)	(98,500)	(226,100)	(257,600)
Operating Expenses, Other	(994,400)	(1,052,100)	(2,083,300)	(2,395,000)
Operating Income	210,300	232,100	429,800	490,200
Total Interest Expense	(47,600)	(45,600)	(95,600)	(93,200)
Other Income/(Loss), Net	6,300	5,500	6,300	7,600
Net Income Attributable to Controlling Interests	102,800	120,900	211,300	251,400
Total Assets	17,855,600		17,855,600		17,981,300
Investments in Property, Plant and Equipment			362,000	319,800
Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Operating Revenues	180,400	186,000	523,000	693,400
Depreciation And Amortization	(16,800)	(17,700)	(32,700)	(35,900)
Operating Expenses, Other	(141,100)	(150,200)	(374,500)	(538,700)
Operating Income	22,500	18,100	115,800	118,800
Total Interest Expense	(10,400)	(9,100)	(20,500)	(18,100)
Other Income/(Loss), Net	100	300	(200)	100
Net Income Attributable to Controlling Interests	8,000	5,300	58,900	61,000
Total Assets	3,122,500		3,122,500		3,104,500
Investments in Property, Plant and Equipment			105,000	67,500
Electric Transmission [Member]
Segment Reporting Information [Line Items]
Operating Revenues	302,500	267,800	585,800	516,800
Depreciation And Amortization	(45,600)	(39,700)	(90,700)	(80,100)
Operating Expenses, Other	(82,500)	(73,100)	(155,500)	(147,200)
Operating Income	174,400	155,000	339,600	289,500
Total Interest Expense	(27,400)	(26,300)	(55,300)	(53,900)
Other Income/(Loss), Net	5,300	5,100	7,900	8,100
Net Income Attributable to Controlling Interests	92,500	80,400	178,200	147,000
Total Assets	8,376,200		8,376,200		8,019,300
Investments in Property, Plant and Equipment			349,100	328,700
Other Segment [Member]
Segment Reporting Information [Line Items]
Operating Revenues	211,100	203,700	425,300	443,700
Depreciation And Amortization	(7,500)	(7,100)	(14,400)	(14,300)
Operating Expenses, Other	(188,100)	(190,700)	(385,400)	(419,900)
Operating Income	15,500	5,900	25,500	9,500
Total Interest Expense	(16,600)	(12,400)	(30,700)	(24,100)
Other Income/(Loss), Net	219,000	220,100	524,400	535,000
Net Income Attributable to Controlling Interests	220,700	217,000	523,100	529,900
Total Assets	13,218,300		13,218,300		13,256,700
Investments in Property, Plant and Equipment			53,100	24,400
Eliminations Segment [Member]
Segment Reporting Information [Line Items]
Operating Revenues	(229,900)	(223,100)	(450,500)	(466,200)
Depreciation And Amortization	500	500	1,100	1,000
Operating Expenses, Other	230,100	223,500	450,700	466,700
Operating Income	700	900	1,300	1,500
Total Interest Expense	1,500	1,100	3,400	2,200
Other Income/(Loss), Net	(222,600)	(218,100)	(528,400)	(532,200)
Net Income Attributable to Controlling Interests	(220,400)	(216,100)	(523,700)	(528,500)
Total Assets	(11,689,900)		(11,689,900)		(11,781,500)
Investments in Property, Plant and Equipment			0	0
Total [Member]
Segment Reporting Information [Line Items]
Operating Revenues	1,767,200	1,817,100	3,822,800	4,330,500
Depreciation And Amortization	(167,800)	(162,500)	(362,800)	(386,900)
Operating Expenses, Other	(1,176,000)	(1,242,600)	(2,548,000)	(3,034,100)
Operating Income	423,400	412,000	912,000	909,500
Total Interest Expense	(100,500)	(92,300)	(198,700)	(187,100)
Other Income/(Loss), Net	8,100	12,900	10,000	18,600
Net Income Attributable to Controlling Interests	203,600	$ 207,500	447,800	460,800
Total Assets	$ 30,882,700		30,882,700		$ 30,580,300
Investments in Property, Plant and Equipment			$ 869,200	$ 740,400