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 September 30, 2015
	or
¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE      SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ____________ to ____________

Commission File Number	Registrant; State of Incorporation; Address; and Telephone Number	I.R.S. Employer Identification No.
1-5324	EVERSOURCE ENERGY (a Massachusetts voluntary association) 300 Cadwell Drive Springfield, Massachusetts 01104 Telephone:  (413) 785-5871	04-2147929

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

1-02301 NSTAR ELECTRIC COMPANY
(a Massachusetts corporation)
800 Boylston Street
Boston, Massachusetts 02199
Telephone:  (617) 424-2000 04-1278810

1-6392 PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
(a New Hampshire corporation)
Energy Park
780 North Commercial Street
Manchester, New Hampshire 03101-1134
Telephone:  (603) 669-4000 02-0181050

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

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 October 31, 2015
Eversource Energy Common shares, $5.00 par value	317,191,249 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
ESTV	Eversource Energy Transmission Ventures, Inc., the parent company of NPT and Renewable Properties, Inc.
NPT	Northern Pass Transmission LLC
Eversource Service	Eversource Energy Service Company (effective January 1, 2014 includes the operations of NSTAR Electric & Gas)
NSTAR Electric & Gas	NSTAR Electric & Gas Corporation, a former Eversource Energy service company (effective January 1, 2014 merged into 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:
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
EPS	Earnings Per Share
ERISA	Employee Retirement Income Security Act of 1974
ES 2014 Form 10-K	The Eversource Energy and Subsidiaries 2014 combined Annual Report on Form 10-K as filed with the SEC
ESOP	Employee Stock Ownership Plan
ESPP	Employee Share Purchase Plan
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

i

GSRP	Greater Springfield Reliability Project
GWh	Gigawatt-Hours
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
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
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
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 Consolidated 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)
		September 30,		December 31,
(Thousands of Dollars)		2015		2014
ASSETS
Current Assets:
	Cash and Cash Equivalents	$	35,781	$	38,703
	Receivables, Net		928,064		856,346
	Unbilled Revenues		197,920		211,758
	Taxes Receivable		12,247		337,307
	Fuel, Materials and Supplies		302,225		349,664
	Regulatory Assets		653,892		672,493
	Marketable Securities		119,702		124,173
	Prepayments and Other Current Assets		117,857		102,021
Total Current Assets			2,367,688		2,692,465
Property, Plant and Equipment, Net			19,406,025		18,647,041
Deferred Debits and Other Assets:
	Regulatory Assets		3,951,752		4,054,086
	Goodwill		3,519,401		3,519,401
	Marketable Securities		476,778		515,025
	Other Long-Term Assets		324,382		349,957
Total Deferred Debits and Other Assets			8,272,313		8,438,469
Total Assets		$	30,046,026	$	29,777,975
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable	$	1,015,500	$	956,825
	Long-Term Debt - Current Portion		228,883		245,583
	Accounts Payable		610,753		868,231
	Obligations to Third Party Suppliers		157,798		115,632
	Regulatory Liabilities		226,061		235,022
	Accumulated Deferred Income Taxes		169,272		160,288
	Other Current Liabilities		563,426		552,800
Total Current Liabilities			2,971,693		3,134,381
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes		4,612,828		4,467,473
	Regulatory Liabilities		517,595		515,144
	Derivative Liabilities		365,692		409,632
	Accrued Pension, SERP and PBOP		1,498,346		1,638,558
	Other Long-Term Liabilities		872,376		874,387
Total Deferred Credits and Other Liabilities			7,866,837		7,905,194
Capitalization:
	Long-Term Debt		8,757,498		8,606,017
	Noncontrolling Interest - Preferred Stock of Subsidiaries		155,568		155,568
	Equity:
	Common Shareholders' Equity:
	Common Shares		1,669,313		1,666,796
	Capital Surplus, Paid In		6,260,663		6,235,834
	Retained Earnings		2,747,977		2,448,661
	Accumulated Other Comprehensive Loss		(73,546)		(74,009)
	Treasury Stock		(309,977)		(300,467)
	Common Shareholders' Equity		10,294,430		9,976,815
Total Capitalization			19,207,496		18,738,400
Total Liabilities and Capitalization		$	30,046,026	$	29,777,975
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 September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars, Except Share Information)			2015		2014		2015		2014
Operating Revenues			$	1,933,105	$	1,892,532	$	6,263,597	$	5,860,736
Operating Expenses:
	Purchased Power, Fuel and Transmission			702,640		716,631		2,549,807		2,318,993
	Operations and Maintenance			327,283		344,092		977,306		1,069,015
	Depreciation			167,884		153,210		495,389		456,224
	Amortization of Regulatory (Liabilities)/Assets, Net			(16,851)		(22,531)		42,587		31,826
	Energy Efficiency Programs			132,107		118,693		380,559		360,228
	Taxes Other Than Income Taxes			150,804		141,527		439,221		421,862
		Total Operating Expenses		1,463,867		1,451,622		4,884,869		4,658,148
Operating Income				469,238		440,910		1,378,728		1,202,588
Interest Expense				92,534		89,738		279,635		272,208
Other Income, Net				5,241		11,860		23,866		19,054
Income Before Income Tax Expense				381,945		363,032		1,122,959		949,434
Income Tax Expense				144,146		126,539		420,640		345,858
Net Income				237,799		236,493		702,319		603,576
Net Income Attributable to Noncontrolling Interests				1,879		1,879		5,639		5,639
Net Income Attributable to Common Shareholders			$	235,920	$	234,614	$	696,680	$	597,937
Basic Earnings Per Common Share			$	0.74	$	0.74	$	2.20	$	1.89
Diluted Earnings Per Common Share			$	0.74	$	0.74	$	2.19	$	1.89
Dividends Declared Per Common Share			$	0.42	$	0.39	$	1.25	$	1.18
Weighted Average Common Shares Outstanding:
	Basic			317,452,212		316,340,691		317,296,107		315,941,904
	Diluted			318,405,269		317,554,925		318,396,042		317,186,490
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	237,799	$	236,493	$	702,319	$	603,576
Other Comprehensive Income, Net of Tax:
	Qualified Cash Flow Hedging Instruments			526		509		1,544		1,528
	Changes in Unrealized (Losses)/Gains on Other Securities			(2,803)		(216)		(3,919)		242
	Changes in Funded Status of Pension, SERP and PBOP    Benefit Plans			764		1,042		2,838		4,089
Other Comprehensive Income, Net of Tax				(1,513)		1,335		463		5,859
Comprehensive Income Attributable to Noncontrolling Interests				(1,879)		(1,879)		(5,639)		(5,639)
Comprehensive Income Attributable to Common Shareholders			$	234,407	$	235,949	$	697,143	$	603,796
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 Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014
Operating Activities:
	Net Income		$	702,319	$	603,576
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
		Depreciation		495,389		456,224
		Deferred Income Taxes		153,353		64,755
		Pension, SERP and PBOP Expense		71,802		74,296
		Pension and PBOP Contributions		(162,880)		(74,681)
		Regulatory Overrecoveries, Net		31,874		290,111
		Amortization of Regulatory Assets, Net		42,587		31,826
		Proceeds from DOE Damages Claim, Net		-		132,138
		Other		(49,548)		(17,096)
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(148,442)		(66,463)
		Fuel, Materials and Supplies		47,380		(27,147)
		Taxes Receivable/Accrued, Net		383,047		26,533
		Accounts Payable		(233,660)		(69,448)
		Other Current Assets and Liabilities, Net		8,370		(20,607)
Net Cash Flows Provided by Operating Activities				1,341,591		1,404,017
Investing Activities:
	Investments in Property, Plant and Equipment			(1,177,285)		(1,117,493)
	Proceeds from Sales of Marketable Securities			556,582		388,352
	Purchases of Marketable Securities			(535,044)		(389,406)
	Other Investing Activities			(2,769)		(4,669)
Net Cash Flows Used in Investing Activities				(1,158,516)		(1,123,216)
Financing Activities:
	Cash Dividends on Common Shares			(397,363)		(356,080)
	Cash Dividends on Preferred Stock			(5,639)		(5,639)
	(Decrease)/Increase in Notes Payable			(387,575)		6,000
	Issuance of Long-Term Debt			825,000		650,000
	Retirements of Long-Term Debt			(216,700)		(576,650)
	Other Financing Activities			(3,720)		(90)
Net Cash Flows Used in Financing Activities				(185,997)		(282,459)
Net Decrease in Cash and Cash Equivalents				(2,922)		(1,658)
Cash and Cash Equivalents - Beginning of Period				38,703		43,364
Cash and Cash Equivalents - End of Period			$	35,781	$	41,706
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)
		September 30,		December 31,
(Thousands of Dollars)		2015		2014
ASSETS
Current Assets:
	Cash	$	13,407	$	2,356
	Receivables, Net		425,955		355,140
	Accounts Receivable from Affiliated Companies		28,266		16,757
	Unbilled Revenues		96,301		102,137
	Taxes Receivable		-		116,148
	Regulatory Assets		243,293		220,344
	Materials and Supplies		44,306		46,664
	Prepaid Property Taxes		52,351		15,597
	Prepayments and Other Current Assets		16,239		22,225
Total Current Assets			920,118		897,368
Property, Plant and Equipment, Net			7,008,603		6,809,664
Deferred Debits and Other Assets:
	Regulatory Assets		1,420,974		1,475,508
	Other Long-Term Assets		145,031		177,568
Total Deferred Debits and Other Assets			1,566,005		1,653,076
Total Assets		$	9,494,726	$	9,360,108
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable to Eversource Parent	$	-	$	133,400
	Long-Term Debt - Current Portion		-		162,000
	Accounts Payable		207,366		272,971
	Accounts Payable to Affiliated Companies		93,257		65,594
	Obligations to Third Party Suppliers		75,659		73,624
	Accrued Taxes		47,973		4,091
	Regulatory Liabilities		136,393		124,722
	Derivative Liabilities		91,372		88,459
	Other Current Liabilities		124,504		149,329
Total Current Liabilities			776,524		1,074,190
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes		1,636,831		1,642,805
	Regulatory Liabilities		76,864		81,298
	Derivative Liabilities		364,691		406,199
	Accrued Pension, SERP and PBOP		284,890		273,854
	Other Long-Term Liabilities		143,642		148,844
Total Deferred Credits and Other Liabilities			2,506,918		2,553,000
Capitalization:
	Long-Term Debt		2,975,316		2,679,951
	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		1,910,651		1,804,869
	Retained Earnings		1,149,500		1,072,477
	Accumulated Other Comprehensive Loss		(735)		(931)
	Common Stockholder's Equity		3,119,768		2,936,767
Total Capitalization			6,211,284		5,732,918
Total Liabilities and Capitalization		$	9,494,726	$	9,360,108
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 September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014		2015		2014
Operating Revenues			$	704,262	$	695,642	$	2,175,733	$	2,017,580
Operating Expenses:
	Purchased Power and Transmission			274,762		255,787		861,562		736,952
	Operations and Maintenance			122,280		127,285		358,324		368,562
	Depreciation			54,809		46,886		159,903		139,598
	Amortization of Regulatory (Liabilities)/Assets, Net			(22,859)		13,098		17,917		62,644
	Energy Efficiency Programs			42,590		41,399		119,360		119,389
	Taxes Other Than Income Taxes			71,563		64,994		201,743		194,105
		Total Operating Expenses		543,145		549,449		1,718,809		1,621,250
Operating Income				161,117		146,193		456,924		396,330
Interest Expense				36,716		38,735		109,463		110,448
Other Income, Net				2,356		6,456		8,576		10,658
Income Before Income Tax Expense				126,757		113,914		356,037		296,540
Income Tax Expense				46,569		30,038		127,845		95,980
Net Income			$	80,188	$	83,876	$	228,192	$	200,560
The accompanying notes are an integral part of these unaudited condensed financial statements.
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	80,188	$	83,876	$	228,192	$	200,560
Other Comprehensive Income, Net of Tax:
	Qualified Cash Flow Hedging Instruments			111		111		333		333
	Changes in Unrealized (Losses)/Gains on Other Securities			(98)		(7)		(137)		8
Other Comprehensive Income, Net of Tax				13		104		196		341
Comprehensive Income			$	80,201	$	83,980	$	228,388	$	200,901
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 Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014
Operating Activities:
	Net Income		$	228,192	$	200,560
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
	Depreciation			159,903		139,598
		Deferred Income Taxes		(11,011)		(14,400)
		Pension, SERP and PBOP Expense, Net of PBOP Contributions		10,654		8,050
		Regulatory Overrecoveries, Net		12,504		62,929
		Amortization of Regulatory Assets, Net		17,917		62,644
		Proceeds from DOE Damages Claim		-		68,610
		Other		(13,048)		(11,290)
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(91,842)		(87,922)
		Taxes Receivable/Accrued, Net		160,031		39,805
		Accounts Payable		(20,485)		16,984
		Other Current Assets and Liabilities, Net		(31,044)		(2,575)
Net Cash Flows Provided by Operating Activities				421,771		482,993
Investing Activities:
	Investments in Property, Plant and Equipment			(359,339)		(371,660)
	Other Investing Activities			(740)		(4,539)
Net Cash Flows Used in Investing Activities				(360,079)		(376,199)
Financing Activities:
	Cash Dividends on Common Stock			(147,000)		(128,400)
	Cash Dividends on Preferred Stock			(4,169)		(4,169)
	Issuance of Long-Term Debt			300,000		250,000
	Retirements of Long-Term Debt			(162,000)		(150,000)
	Decrease in Notes Payable to Eversource Parent			(133,400)		(181,900)
	Capital Contribution from Eversource Parent			105,000		120,000
	Other Financing Activities			(9,072)		(3,268)
Net Cash Flows Used in Financing Activities				(50,641)		(97,737)
Net Increase in Cash				11,051		9,057
Cash - Beginning of Period				2,356		7,237
Cash - End of Period			$	13,407	$	16,294
The accompanying notes are an integral part of these unaudited condensed financial statements.

6

NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
		September 30,		December 31,
(Thousands of Dollars)		2015		2014
ASSETS
Current Assets:
	Cash and Cash Equivalents	$	2,809	$	12,773
	Receivables, Net		303,969		234,481
	Accounts Receivable from Affiliated Companies		17,229		40,353
	Unbilled Revenues		43,288		29,741
	Taxes Receivable		-		144,601
	Materials and Supplies		52,315		74,179
	Regulatory Assets		223,520		198,710
	Prepayments and Other Current Assets		8,862		10,815
Total Current Assets			651,992		745,653
Property, Plant and Equipment, Net			5,545,082		5,335,436
Deferred Debits and Other Assets:
	Regulatory Assets		1,179,996		1,179,100
	Other Long-Term Assets		60,339		73,051
Total Deferred Debits and Other Assets			1,240,335		1,252,151
Total Assets		$	7,437,409	$	7,333,240
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable	$	258,500	$	302,000
	Long-Term Debt - Current Portion		200,000		4,700
	Accounts Payable		172,521		217,311
	Accounts Payable to Affiliated Companies		25,515		63,517
	Obligations to Third Party Suppliers		70,607		34,824
	Renewable Portfolio Standards Compliance Obligations		67,828		35,698
	Accrued Taxes		66,474		4,191
	Accumulated Deferred Income Taxes		92,183		55,136
	Regulatory Liabilities		12,319		49,611
	Other Current Liabilities		88,905		111,800
Total Current Liabilities			1,054,852		878,788
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes		1,546,801		1,527,667
	Regulatory Liabilities		267,342		262,738
	Accrued Pension, SERP and PBOP		211,891		235,529
	Other Long-Term Liabilities		122,026		129,279
Total Deferred Credits and Other Liabilities			2,148,060		2,155,213
Capitalization:
	Long-Term Debt		1,592,727		1,792,712
	Preferred Stock Not Subject to Mandatory Redemption		43,000		43,000
	Common Stockholder's Equity:
	Common Stock		-		-
	Capital Surplus, Paid In		995,378		994,130
	Retained Earnings		1,603,134		1,468,955
	Accumulated Other Comprehensive Income		258		442
	Common Stockholder's Equity		2,598,770		2,463,527
Total Capitalization			4,234,497		4,299,239
Total Liabilities and Capitalization		$	7,437,409	$	7,333,240
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 September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014		2015		2014
Operating Revenues			$	750,724	$	727,909	$	2,134,728	$	1,955,609
Operating Expenses:
	Purchased Power and Transmission			299,040		317,784		984,035		879,773
	Operations and Maintenance			83,486		79,705		228,740		244,610
	Depreciation			49,101		47,455		146,818		140,996
	Amortization of Regulatory Assets/(Liabilities), Net			2,257		(15,063)		(10,643)		(916)
	Energy Efficiency Programs			67,693		56,915		164,843		145,499
	Taxes Other Than Income Taxes			34,982		34,513		95,821		99,121
		Total Operating Expenses		536,559		521,309		1,609,614		1,509,083
Operating Income				214,165		206,600		525,114		446,526
Interest Expense				18,992		17,338		57,218		59,091
Other Income, Net				513		3,287		3,649		3,011
Income Before Income Tax Expense				195,686		192,549		471,545		390,446
Income Tax Expense				77,062		76,975		187,397		156,655
Net Income			$	118,624	$	115,574	$	284,148	$	233,791
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	118,624	$	115,574	$	284,148	$	233,791
Other Comprehensive Loss, Net of Tax:
	Changes in Funded Status of SERP Benefit Plan			(2)		-		(184)		-
Other Comprehensive Loss, Net of Tax				(2)		-		(184)		-
Comprehensive Income			$	118,622	$	115,574	$	283,964	$	233,791
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 Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014
Operating Activities:
	Net Income		$	284,148	$	233,791
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
		Depreciation		146,818		140,996
		Deferred Income Taxes		54,188		(39,399)
		Pension and PBOP Contributions, Net of Pension, SERP and PBOP Expense		(1,138)		(11,046)
		Regulatory (Under)/Over Recoveries, Net		(48,903)		155,357
		Amortization of Regulatory Liabilities, Net		(10,643)		(916)
		Proceeds from DOE Damages Claim		-		30,193
		Other		(34,223)		(41,601)
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(107,711)		(47,770)
		Materials and Supplies		21,863		(20,837)
		Taxes Receivable/Accrued, Net		207,516		60,252
		Accounts Payable		(41,447)		(40,594)
		Accounts Receivable from/Payable to Affiliates, Net		(14,878)		66,758
		Other Current Assets and Liabilities, Net		46,671		32,340
Net Cash Flows Provided by Operating Activities				502,261		517,524
Investing Activities:
	Investments in Property, Plant and Equipment			(314,055)		(309,248)
Net Cash Flows Used in Investing Activities				(314,055)		(309,248)
Financing Activities:
	Cash Dividends on Common Stock			(148,500)		(253,000)
	Cash Dividends on Preferred Stock			(1,470)		(1,470)
	(Decrease)/Increase in Notes Payable			(43,500)		56,000
	Issuance of Long-Term Debt			-		300,000
	Retirements of Long-Term Debt			(4,700)		(301,650)
	Other Financing Activities			-		(5,137)
Net Cash Flows Used in Financing Activities				(198,170)		(205,257)
Net (Decrease)/Increase in Cash and Cash Equivalents				(9,964)		3,019
Cash and Cash Equivalents - Beginning of Period				12,773		8,021
Cash and Cash Equivalents - End of Period			$	2,809	$	11,040
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)
		September 30,		December 31,
(Thousands of Dollars)		2015		2014
ASSETS
Current Assets:
	Cash	$	2,103	$	489
	Receivables, Net		91,700		80,151
	Accounts Receivable from Affiliated Companies		14,630		3,194
	Unbilled Revenues		34,932		40,181
	Fuel, Materials and Supplies		143,983		148,139
	Regulatory Assets		89,513		111,705
	Prepayments and Other Current Assets		22,125		42,392
Total Current Assets			398,986		426,251
Property, Plant and Equipment, Net			2,768,206		2,635,844
Deferred Debits and Other Assets:
	Regulatory Assets		272,360		293,115
	Other Long-Term Assets		35,075		39,228
Total Deferred Debits and Other Assets			307,435		332,343
Total Assets		$	3,474,627	$	3,394,438
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable to Eversource Parent	$	137,300	$	90,500
	Accounts Payable		76,330		93,349
	Accounts Payable to Affiliated Companies		25,239		33,734
	Regulatory Liabilities		11,338		16,044
	Accumulated Deferred Income Taxes		34,699		36,164
	Other Current Liabilities		47,589		38,969
Total Current Liabilities			332,495		308,760
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes		629,055		587,292
	Regulatory Liabilities		49,680		51,372
	Accrued Pension, SERP and PBOP		97,167		93,243
	Other Long-Term Liabilities		48,543		50,155
Total Deferred Credits and Other Liabilities			824,445		782,062
Capitalization:
	Long-Term Debt		1,076,336		1,076,286
	Common Stockholder's Equity:
	Common Stock		-		-
	Capital Surplus, Paid In		748,634		748,240
	Retained Earnings		499,450		486,459
	Accumulated Other Comprehensive Loss		(6,733)		(7,369)
	Common Stockholder's Equity		1,241,351		1,227,330
Total Capitalization			2,317,687		2,303,616
Total Liabilities and Capitalization		$	3,474,627	$	3,394,438
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 September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014		2015		2014
Operating Revenues			$	234,364	$	223,664	$	761,086	$	735,123
Operating Expenses:
	Purchased Power, Fuel and Transmission			53,017		64,397		200,533		247,992
	Operations and Maintenance			65,190		65,563		200,085		198,025
	Depreciation			26,592		24,568		77,989		73,247
	Amortization of Regulatory Assets/(Liabilities), Net			1,967		(9,734)		29,148		(17,565)
	Energy Efficiency Programs			3,873		3,766		11,001		10,897
	Taxes Other Than Income Taxes			20,104		18,702		61,435		53,051
		Total Operating Expenses		170,743		167,262		580,191		565,647
Operating Income				63,621		56,402		180,895		169,476
Interest Expense				11,647		11,024		34,582		33,995
Other Income, Net				685		461		2,313		1,673
Income Before Income Tax Expense				52,659		45,839		148,626		137,154
Income Tax Expense				20,158		17,603		56,135		52,199
Net Income			$	32,501	$	28,236	$	92,491	$	84,955
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	32,501	$	28,236	$	92,491	$	84,955
Other Comprehensive Income, Net of Tax:
	Qualified Cash Flow Hedging Instruments			291		290		872		871
	Changes in Unrealized (Losses)/Gains on Other Securities			(169)		(13)		(236)		14
Other Comprehensive Income, Net of Tax				122		277		636		885
Comprehensive Income			$	32,623	$	28,513	$	93,127	$	85,840
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 Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014
Operating Activities:
	Net Income		$	92,491	$	84,955
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
		Depreciation		77,989		73,247
		Deferred Income Taxes		42,563		67,827
		Regulatory Overrecoveries, Net		2,639		16,813
		Amortization of Regulatory Assets/(Liabilities), Net		29,148		(17,565)
		Proceeds from DOE Damages Claim		-		14,453
		Other		10,894		10,834
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(25,126)		(7,467)
		Fuel, Materials and Supplies		4,156		(17,350)
		Taxes Receivable/Accrued, Net		9,026		(24,108)
		Accounts Payable		(20,058)		(9,297)
		Other Current Assets and Liabilities, Net		20,141		13,470
Net Cash Flows Provided by Operating Activities				243,863		205,812
Investing Activities:
	Investments in Property, Plant and Equipment			(209,522)		(170,127)
	Other Investing Activities			241		(148)
Net Cash Flows Used in Investing Activities				(209,281)		(170,275)
Financing Activities:
	Cash Dividends on Common Stock			(79,500)		(49,500)
	Increase in Notes Payable to Eversource Parent			46,800		66,800
	Retirements of Long-Term Debt			-		(50,000)
	Other Financing Activities			(268)		(217)
Net Cash Flows Used in Financing Activities				(32,968)		(32,917)
Net Increase in Cash				1,614		2,620
Cash - Beginning of Period				489		130
Cash - End of Period			$	2,103	$	2,750
The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

12

WESTERN MASSACHUSETTS ELECTRIC COMPANY
CONDENSED BALANCE SHEETS
(Unaudited)
		September 30,		December 31,
(Thousands of Dollars)		2015		2014
ASSETS
Current Assets:
	Cash	$	658	$	-
	Receivables, Net		62,889		51,066
	Accounts Receivable from Affiliated Companies		24,221		7,851
	Unbilled Revenues		14,517		15,146
	Taxes Receivable		49		18,126
	Regulatory Assets		48,805		51,923
	Marketable Securities		40,459		28,658
	Prepayments and Other Current Assets		6,983		7,607
Total Current Assets			198,581		180,377
Property, Plant and Equipment, Net			1,531,705		1,461,321
Deferred Debits and Other Assets:
	Regulatory Assets		133,697		146,307
	Marketable Securities		17,888		29,452
	Other Long-Term Assets		26,709		22,018
Total Deferred Debits and Other Assets			178,294		197,777
Total Assets		$	1,908,580	$	1,839,475
LIABILITIES AND CAPITALIZATION
Current Liabilities:
	Notes Payable to Eversource Parent	$	126,200	$	21,400
	Long-Term Debt - Current Portion		-		50,000
	Accounts Payable		33,960		53,732
	Accounts Payable to Affiliated Companies		21,496		14,328
	Regulatory Liabilities		24,267		22,486
	Accumulated Deferred Income Taxes		13,403		18,089
	Other Current Liabilities		28,961		24,080
Total Current Liabilities			248,287		204,115
Deferred Credits and Other Liabilities:
	Accumulated Deferred Income Taxes		422,753		416,822
	Regulatory Liabilities		11,926		10,835
	Accrued Pension, SERP and PBOP		18,320		17,705
	Other Long-Term Liabilities		36,849		33,747
Total Deferred Credits and Other Liabilities			489,848		479,109
Capitalization:
	Long-Term Debt		577,781		578,471
	Common Stockholder's Equity:
	Common Stock		10,866		10,866
	Capital Surplus, Paid In		391,398		391,256
	Retained Earnings		193,344		178,834
	Accumulated Other Comprehensive Loss		(2,944)		(3,176)
	Common Stockholder's Equity		592,664		577,780
Total Capitalization			1,170,445		1,156,251
Total Liabilities and Capitalization		$	1,908,580	$	1,839,475
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 September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014		2015		2014
Operating Revenues			$	125,093	$	118,145	$	403,151	$	363,843
Operating Expenses:
	Purchased Power and Transmission			36,465		43,926		149,182		130,977
	Operations and Maintenance			21,762		20,820		61,651		67,085
	Depreciation			11,196		10,506		32,420		31,144
	Amortization of Regulatory Assets/(Liabilities), Net			3,930		(8,519)		11,194		(7,778)
	Energy Efficiency Programs			12,107		10,983		32,701		33,096
	Taxes Other Than Income Taxes			9,599		9,200		28,430		25,679
		Total Operating Expenses		95,059		86,916		315,578		280,203
Operating Income				30,034		31,229		87,573		83,640
Interest Expense				5,901		6,576		19,014		18,929
Other Income, Net				587		502		2,406		1,670
Income Before Income Tax Expense				24,720		25,155		70,965		66,381
Income Tax Expense				9,749		10,490		28,555		26,596
Net Income			$	14,971	$	14,665	$	42,410	$	39,785
The accompanying notes are an integral part of these unaudited condensed financial statements.
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
Net Income			$	14,971	$	14,665	$	42,410	$	39,785
Other Comprehensive Income, Net of Tax:
	Qualified Cash Flow Hedging Instruments			101		85		270		254
	Changes in Unrealized (Losses)/Gains on Other Securities			(27)		(2)		(38)		2
Other Comprehensive Income, Net of Tax				74		83		232		256
Comprehensive Income			$	15,045	$	14,748	$	42,642	$	40,041
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 Nine Months Ended September 30,
(Thousands of Dollars)			2015		2014
Operating Activities:
	Net Income		$	42,410	$	39,785
	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
		Depreciation		32,420		31,144
		Deferred Income Taxes		5,531		13,479
		Regulatory Overrecoveries, Net		4,024		33,630
		Amortization of Regulatory Assets/(Liabilities), Net		11,194		(7,778)
		Proceeds from DOE Damages Claim		-		18,883
		Other		(4,500)		615
	Changes in Current Assets and Liabilities:
		Receivables and Unbilled Revenues, Net		(32,664)		36,075
		Taxes Receivable/Accrued, Net		24,064		(15,831)
		Accounts Payable		(14,018)		(12,847)
		Other Current Assets and Liabilities, Net		(463)		(16,551)
Net Cash Flows Provided by Operating Activities				67,998		120,604
Investing Activities:
	Investments in Property, Plant and Equipment			(93,705)		(82,546)
	Proceeds from Sales of Marketable Securities			71,110		58,788
	Purchases of Marketable Securities			(71,625)		(59,280)
Net Cash Flows Used in Investing Activities				(94,220)		(83,038)
Financing Activities:
	Cash Dividends on Common Stock			(27,900)		(49,000)
	Increase in Notes Payable to Eversource Parent			104,800		13,200
	Retirements of Long-Term Debt			(50,000)		-
	Other Financing Activities			(20)		(29)
Net Cash Flows Provided by/(Used in) Financing Activities				26,880		(35,829)
Net Increase in Cash				658		1,737
Cash - Beginning of Period				-		-
Cash - End of Period			$	658	$	1,737
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 CONSOLIDATED 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 consolidated 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.  

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

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 entirety of this combined Quarterly Report on Form 10-Q, the first and second quarter 2015 combined Quarterly Report on Form 10-Q and the 2014 combined Annual Report on Form 10-K of Eversource, CL&P, NSTAR Electric, PSNH and WMECO, which were 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 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 September 30, 2015 and December 31, 2014, the results of operations and comprehensive income for the three and nine months ended September 30, 2015 and 2014, and the cash flows for the nine months ended September 30, 2015 and 2014.  The results of operations and comprehensive income for the three and nine months ended September 30, 2015 and 2014 and the cash flows for the nine months ended September 30, 2015 and 2014 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.  

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.

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, as a result of which ASU 2014-09 is required to be applied in the first quarter of 2018, with 2017 application permitted.  The Company is reviewing the requirements of ASU 2014-09 and will implement the standard in the first quarter of 2018.  The ASU is not expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

In April 2015, the FASB issued ASU 2015-03, Simplifying the Presentation of Debt Issuance Costs, that changes the balance sheet presentation of debt issuance costs.  Under the standard, issuance costs related to debt will be presented on the balance sheet as a direct deduction from the carrying amount of the debt liability rather than as a deferred cost as required by current guidance.  The new accounting guidance is effective for interim and annual periods beginning in the first quarter of 2016 with early adoption permitted.  Upon adoption, an entity must apply the new guidance retrospectively to all prior periods presented in the financial statements.  The Company intends to adopt the new guidance at December 31, 2015.  

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Management does not expect the adoption of this standard to have a material effect on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

C.

Provision for Uncollectible Accounts

Eversource, including CL&P, NSTAR Electric, PSNH and WMECO, presents its receivables at estimated net realizable value by maintaining a provision for uncollectible accounts.  This provision is determined based upon a variety of judgments and factors, including the application of an estimated uncollectible percentage to each receivable aging category.  The estimate is based upon historical collection and write-off experience and management's 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 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 to also recover in rates amounts associated with certain uncollectible hardship accounts receivable.  Uncollectible customer account balances, which are expected to be recovered in rates, are included in Regulatory Assets or Other Long-Term Assets.

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

	Total Provision for Uncollectible Accounts				Uncollectible Hardship
(Millions of Dollars)	As of September 30, 2015		As of December 31, 2014		As of September 30, 2015		As of December 31, 2014
Eversource	$	185.8	$	175.3	$	86.6	$	91.5
CL&P		79.5		84.3		64.9		74.0
NSTAR Electric		46.4		40.7		-		-
PSNH		9.4		7.7		-		-
WMECO		13.2		9.9		7.7		6.2

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 and nonrecurring fair value measurements of nonfinancial assets such as goodwill and AROs, and is also used to estimate the 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 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.  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 payments in Taxes Other Than Income Taxes on the statements of income as follows:

	For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2015		September 30, 2014		September 30, 2015		September 30, 2014
Eversource	$	37.8	$	35.0	$	112.9	$	114.6
CL&P		35.5		32.5		98.0		99.0

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

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G. Supplemental Cash Flow Information
Non-cash investing activities include plant additions included in Accounts Payable as follows:
(Millions of Dollars)	As of September 30, 2015		As of September 30, 2014
Eversource	$	160.7		128.9
CL&P		46.0		52.2
NSTAR Electric		31.2		18.1
PSNH		33.8		21.0
WMECO		15.5		10.0

H.

Severance Benefits

Eversource recorded severance benefit expense of $1 million and $0.7 million for the three months ended September 30, 2015 and 2014, respectively, and $2.6 million and $6.5 million for the nine months ended September 30, 2015 and 2014, respectively, in connection with reorganizational and cost saving initiatives, and, in 2014, the partial outsourcing of information technology functions.  As of September 30, 2015 and December 31, 2014, the severance accrual totaled $7.1 million and $10.4 million, respectively, and was included in Other Current Liabilities on the balance sheets.  

I.

Income Taxes

Income tax expense is estimated for each of the jurisdictions in which Eversource operates and is recorded on the quarter using an estimated annualized effective tax rate.  This process to record income tax expense involves estimating current and deferred income tax expense or benefit and the impact of temporary differences resulting from differing treatment of items for financial reporting and income tax return reporting purposes.  Such differences are the result of timing of the deduction for expenses, as well as any impact of permanent differences, non-tax deductible expenses, or other items that directly impact the income tax return as a result of a regulatory activity (flow-through items).  The temporary differences and flow-through items result in deferred tax assets and liabilities that are included in the balance sheets.

Part of the annual process in making adjustments to these estimates is reconciling the provision for income taxes made during the income tax estimation process to what was filed in the income tax return (return to provision).  In the third quarter of 2015, Eversource and CL&P recorded an $8 million and $4.2 million charge, respectively, as a result of reconciling and adjusting its 2014 provision for income taxes to what was filed on its 2014 income tax return.  Concurrently, Eversource and CL&P recorded a reversal of state tax reserves in the third quarter of 2015, which resulted in a $5.9 million and $2.2 million benefit, respectively.

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 consider 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 that 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 are as follows:

	As of September 30, 2015		As of December 31, 2014
(Millions of Dollars)	Eversource		Eversource
Benefit Costs	$	1,941.8	$	2,016.0
Derivative Liabilities		412.8		425.5
Income Taxes, Net		635.8		635.3
Storm Restoration Costs		461.3		502.8
Goodwill-related		490.0		505.4
Regulatory Tracker Mechanisms		373.1		350.5
Contractual Obligations - Yankee Companies		142.0		123.8
Other Regulatory Assets		148.9		167.3
Total Regulatory Assets		4,605.7		4,726.6
Less:  Current Portion		653.9		672.5
Total Long-Term Regulatory Assets	$	3,951.8	$	4,054.1

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	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Benefit Costs	$	434.8	$	486.8	$	171.1	$	84.2	$	445.4	$	515.9	$	174.3	$	85.0
Derivative Liabilities		406.9		1.4		-		-		410.9		4.5		-		-
Income Taxes, Net		435.7		83.5		34.2		30.5		437.7		83.7		38.0		35.5
Storm Restoration Costs		286.5		113.5		36.3		25.0		319.6		103.7		47.7		31.8
Goodwill-related		-		420.7		-		-		-		433.9		-		-
Regulatory Tracker Mechanisms		16.0		228.0		85.4		30.1		16.1		141.4		103.5		33.0
Other Regulatory Assets		84.4		69.6		34.9		12.7		66.1		94.7		41.3		12.9
Total Regulatory Assets		1,664.3		1,403.5		361.9		182.5		1,695.8		1,377.8		404.8		198.2
Less:  Current Portion		243.3		223.5		89.5		48.8		220.3		198.7		111.7		51.9
Total Long-Term Regulatory Assets	$	1,421.0	$	1,180.0	$	272.4	$	133.7	$	1,475.5	$	1,179.1	$	293.1	$	146.3

Regulatory Costs in Other Long-Term Assets:  The Regulated companies had $59.4 million ($2.4 million for CL&P, $21.1 million for NSTAR Electric, $3.2 million for PSNH and $16.2 million for WMECO) and $60.5 million ($1.3 million for CL&P, $33.2 million for NSTAR Electric, $0.9 million for PSNH, and $11 million for WMECO) of additional regulatory costs as of September 30, 2015 and December 31, 2014, respectively, that were included in Other Long-Term Assets on the balance sheets.  These amounts represent incurred costs for which recovery has not yet been specifically approved by the applicable regulatory agency.  However, based on regulatory policies or past precedent on similar costs, management believes it is probable that these costs will ultimately be approved and recovered from customers in rates.  The NSTAR Electric balance as of September 30, 2015 and December 31, 2014 primarily related to costs deferred in connection with the basic service bad debt adder.  See below, within the "2015 Regulatory Developments" section of this footnote for further information.  

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

	As of September 30, 2015		As of December 31, 2014
(Millions of Dollars)	Eversource		Eversource
Cost of Removal	$	433.7	$	439.9
Regulatory Tracker Mechanisms		215.9		192.3
AFUDC - Transmission		66.2		67.1
Other Regulatory Liabilities		27.9		50.8
Total Regulatory Liabilities		743.7		750.1
Less:  Current Portion		226.1		235.0
Total Long-Term Regulatory Liabilities	$	517.6	$	515.1

	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Cost of Removal	$	17.2	$	257.7	$	49.1	$	2.0	$	19.7	$	258.3	$	50.3	$	1.1
Regulatory Tracker Mechanisms		131.1		13.0		8.6		24.2		122.6		20.7		14.2		22.3
AFUDC - Transmission		51.8		5.4		-		9.0		53.6		4.4		-		9.1
Other Regulatory Liabilities		13.2		3.5		3.3		1.0		10.1		28.9		2.9		0.8
Total Regulatory Liabilities		213.3		279.6		61.0		36.2		206.0		312.3		67.4		33.3
Less:  Current Portion		136.4		12.3		11.3		24.3		124.7		49.6		16.0		22.5
Total Long-Term Regulatory Liabilities	$	76.9	$	267.3	$	49.7	$	11.9	$	81.3	$	262.7	$	51.4	$	10.8

2015 Regulatory Developments:

FERC ROE Complaints:  As a result of the March 3, 2015 FERC order in the pending ROE complaint proceedings described in Note 8C, "Commitments and Contingencies – FERC ROE Complaints," in 2015, Eversource recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO.   The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues.  

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

NSTAR Electric Basic Service Bad Debt Adder:  On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006.  As a result of the DPU order, NSTAR Electric increased its regulatory assets and reduced operations and maintenance expense by $24.2 million in the first quarter of 2015, resulting in after-tax earnings of $14.5 million.  On May 5, 2015, NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers beginning July 1, 2015.  On June 24, 2015, the DPU delayed the effective date of NSTAR Electric’s proposed rate increase from July 1, 2015 to November 1, 2015 to allow for the DPU staff to review the reconciliations.  NSTAR Electric requested recovery from customers effective January 1, 2016 in briefs filed with the DPU in October 2015.  On October 27, 2015, the DPU delayed the effective date of the rate increase from November 1, 2015 to December 1, 2015 to allow the DPU staff additional time to review the reconciliations.  NSTAR Electric expects a decision from the DPU in the fourth quarter of 2015.

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CL&P Distribution Rates:  On July 2, 2015, PURA issued a final order that allows for an increase to rate base of approximately $163 million associated with ADIT, including a regulatory asset to recover the incremental revenue requirement for the period December 1, 2014 through November 30, 2015 over a subsequent two-year period.  The rate base increase provided an increase to total allowed annual revenue requirements of $18.4 million beginning December 1, 2014.  Of that amount, $15.3 million has been recorded as a regulatory asset through September 30, 2015, with a corresponding increase in Operating Revenues.

3.

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

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

		As of September 30, 2015		As of December 31, 2014
(Millions of Dollars)		Eversource		Eversource
Distribution - Electric		$	12,821.6	$	12,495.2
Distribution - Natural Gas			2,657.5		2,595.4
Transmission			7,260.6		6,930.7
Generation			1,180.0		1,170.9
Electric and Natural Gas Utility			23,919.7		23,192.2
Other (1)			555.3		551.3
Property, Plant and Equipment, Gross			24,475.0		23,743.5
Less:  Accumulated Depreciation
	Electric and Natural Gas Utility		(6,041.5)		(5,777.8)
	Other		(247.6)		(231.8)
Total Accumulated Depreciation			(6,289.1)		(6,009.6)
Property, Plant and Equipment, Net			18,185.9		17,733.9
Construction Work in Progress			1,220.1		913.1
Total Property, Plant and Equipment, Net		$	19,406.0	$	18,647.0

⁽¹⁾

These assets are primarily comprised of building improvements, computer software, hardware and equipment and telecommunications assets at Eversource Service and Eversource's unregulated companies.

	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Distribution	$	5,289.6	$	5,001.9	$	1,772.0	$	798.1	$	5,158.8	$	4,895.5	$	1,696.7	$	784.2
Transmission		3,480.5		1,995.3		839.9		896.7		3,274.0		1,928.5		789.7		891.0
Generation		-		-		1,145.5		34.5		-		-		1,136.5		34.4
Property, Plant and    Equipment, Gross		8,770.1		6,997.2		3,757.4		1,729.3		8,432.8		6,824.0		3,622.9		1,709.6
Less:  Accumulated Depreciation		(2,007.9)		(1,857.9)		(1,149.6)		(302.6)		(1,928.0)		(1,761.4)		(1,090.0)		(297.4)
Property, Plant and Equipment, Net		6,762.2		5,139.3		2,607.8		1,426.7		6,504.8		5,062.6		2,532.9		1,412.2
Construction Work in Progress		246.4		405.8		160.4		105.0		304.9		272.8		102.9		49.1
Total Property, Plant and   Equipment, Net	$	7,008.6	$	5,545.1	$	2,768.2	$	1,531.7	$	6,809.7	$	5,335.4	$	2,635.8	$	1,461.3

As of September 30, 2015, PSNH had $1.1 billion in gross generation utility plant assets and Accumulated Depreciation of $514 million.  These generation assets are the subject of a divestiture agreement entered into on June 10, 2015 between Eversource, PSNH and key New Hampshire officials whereby, among other resolutions, PSNH has agreed to sell these generation assets.  Upon completion of the sale, all remaining stranded costs will be recovered via bonds that will be secured by a non-bypassable charge on the bills of 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 amount recorded as current or long-term derivative asset or liability:

		As of September 30, 2015						As of December 31, 2014
		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 3:
	Eversource	$	16.6	$	(10.8)	$	5.8	$	16.2	$	(6.6)	$	9.6
	CL&P		16.6		(10.8)		5.8		16.1		(6.6)		9.5
	NSTAR Electric		-		-		-		0.1		-		0.1
Long-Term Derivative Assets:
Level 3:
	Eversource	$	67.7	$	(22.2)	$	45.5	$	93.5	$	(19.2)	$	74.3
	CL&P		65.6		(22.2)		43.4		93.5		(19.2)		74.3
	NSTAR Electric		2.1		-		2.1		-		-		-
Current Derivative Liabilities:
Level 2:
	Eversource	$	(4.6)	$	-	$	(4.6)	$	(9.8)	$	-	$	(9.8)
Level 3:
	Eversource		(92.6)		-		(92.6)		(90.0)		-		(90.0)
	CL&P		(91.4)		-		(91.4)		(88.5)		-		(88.5)
	NSTAR Electric		(1.2)		-		(1.2)		(1.5)		-		(1.5)
Long-Term Derivative Liabilities:
Level 2:
	Eversource	$	-	$	-	$	-	$	(0.3)	$	-	$	(0.3)
Level 3:
	Eversource		(365.7)		-		(365.7)		(409.3)		-		(409.3)
	CL&P		(364.7)		-		(364.7)		(406.2)		-		(406.2)
	NSTAR Electric		(1.0)		-		(1.0)		(3.1)		-		(3.1)

⁽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 each contract allocated to CL&P and 20 percent allocated to UI.  The combined capacity of these contracts is 787 MW.  The capacity contracts extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market price received in the ISO-NE capacity markets.  In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020.   

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

As of September 30, 2015 and December 31, 2014, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately 9.9 million and 8.8 million MMBtu of natural gas, respectively.

For the three months ended September 30, 2015 and 2014, there were losses of $8.8 million and $15.7 million, respectively, deferred as regulatory costs, which reflect the current change in fair value associated with Eversource's derivative contracts. For the nine months ended September 30, 2015 and 2014, there were losses of $58.9 million and gains of $149.9 million, respectively.  

Credit Risk

Certain of Eversource's derivative contracts contain credit risk contingent provisions.  These provisions require Eversource to maintain investment grade credit ratings from the major rating agencies and to post collateral for contracts in a net liability position over specified credit limits. As of September 30, 2015 and December 31, 2014, Eversource had approximately $4.6 million and $10 million, respectively, of derivative contracts in a net liability position that were subject to credit risk contingent provisions and would have been required to post additional collateral of approximately $4.7 million and $10 million, respectively, if Eversource parent's unsecured debt credit ratings had been downgraded to below investment grade.  

Fair Value Measurements of Derivative Instruments

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

21

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 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 September 30, 2015						As of December 31, 2014
		Range				Period Covered		Range				Period Covered
Capacity Prices:
Eversource	$	10.30	-	13.13	per kW-Month	2016 - 2026	$	5.30	-	12.98	per kW-Month	2016 - 2026
CL&P	$	10.81	-	12.60	per kW-Month	2019 - 2026	$	11.08	-	12.98	per kW-Month	2018 - 2026
NSTAR Electric	$	10.30	-	13.13	per kW-Month	2016 - 2019	$	5.30	-	11.10	per kW-Month	2016 - 2019
Forward Reserve:
Eversource, CL&P	$	2.00			per kW-Month	2016 - 2024	$	5.80	-	9.50	per kW-Month	2015 - 2024
REC Prices:
Eversource, NSTAR Electric	$	45	-	50	per REC	2015 - 2018	$	38	-	56	per REC	2015 - 2018

Exit price premiums of 6 percent through 23 percent are also applied on these contracts and reflect 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 the risk premiums would increase the fair value of the derivative liabilities.  Changes in these fair values are recorded as a regulatory asset or liability and would not impact net income.  

Valuations using significant unobservable inputs:  The following table presents changes in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis.  The derivative assets and liabilities are presented on a net basis.

	For the Three Months Ended September 30,
	2015						2014
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(422.4)	$	(420.2)	$	(2.2)	$	(430.9)	$	(424.6)	$	(6.3)
Net Realized/Unrealized Gains/(Losses)   Included in Regulatory Assets and Liabilities		(6.0)		(7.6)		1.6		(13.6)		(15.0)		1.4
Settlements		21.4		20.9		0.5		21.0		18.5		2.5
Fair Value as of End of Period	$	(407.0)	$	(406.9)	$	(0.1)	$	(423.5)	$	(421.1)	$	(2.4)
	For the Nine Months Ended September 30,
	2015						2014
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(415.4)	$	(410.9)	$	(4.5)	$	(635.2)	$	(630.6)	$	(7.3)
Net Realized/Unrealized Gains/(Losses)   Included in Regulatory Assets and Liabilities		(55.3)		(56.6)		1.3		147.6		149.4		0.9
Settlements		63.7		60.6		3.1		64.1		60.1		4.0
Fair Value as of End of Period	$	(407.0)	$	(406.9)	$	(0.1)	$	(423.5)	$	(421.1)	$	(2.4)

5.

MARKETABLE SECURITIES

Eversource maintains trusts to fund certain non-qualified executive benefits and WMECO maintains a spent nuclear fuel trust to fund WMECO's prior period spent nuclear fuel liability.  These trusts hold marketable securities.  These trusts are not subject to regulatory oversight by state or federal agencies.  In addition, CYAPC and YAEC maintain legally restricted trusts, each of which holds marketable securities, for paying the decommissioning and fuel removal obligations of their nuclear fuel storage facilities.

Trading Securities:  Eversource has elected to record certain equity securities as trading securities, with the changes in fair values recorded in Other Income, Net on the statements of income.  As of September 30, 2015 and December 31, 2014, these securities were classified as Level 1 in the fair value hierarchy and totaled $14.2 million and $85.1 million, respectively.   Net losses on these securities of $0.5 million and $1.9 million for the

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three months ended September 30, 2015 and 2014, respectively, and net gains of $1.6 million and $1.9 million, respectively, for the nine months ended September 30, 2015 and 2014, respectively, were recorded in Other Income, Net on the statements of income.  Dividend income is recorded in Other Income, Net when dividends are declared.  In 2015, certain of the securities classified as trading securities were sold and the proceeds were re-invested in equity securities designated as available-for-sale securities.  

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

		As of September 30, 2015								As of December 31, 2014
				Pre-Tax		Pre-Tax						Pre-Tax		Pre-Tax
		Amortized		Unrealized		Unrealized				Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains		Losses		Fair Value		Cost		Gains		Losses		Fair Value
Eversource
	Debt Securities (1) (2)	$	311.6	$	3.6	$	(0.8)	$	314.4	$	313.0	$	7.5	$	(0.3)	$	320.2
	Equity Securities (1)		220.0		53.9		(6.0)		267.9		160.6		73.3		-		233.9
WMECO
	Debt Securities (2)		58.3		-		-		58.3		58.2		-		(0.1)		58.1

⁽¹⁾

Amounts include CYAPC's and YAEC's marketable securities held in nuclear decommissioning trusts of $430.2 million and $450.8 million as of September 30, 2015 and December 31, 2014, respectively, which are legally restricted and can only be used for the costs of decommissioning and fuel removal of the nuclear fuel storage facilities owned by these companies. Unrealized gains and losses for the nuclear decommissioning trusts are recorded in Marketable Securities with the corresponding offset to Other Long-Term Liabilities on the balance sheets, with no impact on the statements of income.  

⁽²⁾

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

Unrealized Losses and Other-than-Temporary Impairment:  There have been no significant unrealized losses, other-than-temporary impairments or credit losses for Eversource or WMECO.  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, Other Long-Term Assets for WMECO, 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 WMECO trust and the CYAPC and YAEC nuclear decommissioning trusts to compute the realized gains and losses on the sale of available-for-sale securities.

Contractual Maturities:  As of September 30, 2015, the contractual maturities of available-for-sale debt securities were as follows:  

	Eversource				WMECO
	Amortized				Amortized
(Millions of Dollars)	Cost		Fair Value		Cost		Fair Value
Less than one year (1)	$	68.1	$	68.1	$	40.5	$	40.5
One to five years		67.6		68.0		14.2		14.2
Six to ten years		56.9		56.9		0.5		0.5
Greater than ten years		119.0		121.4		3.1		3.1
Total Debt Securities	$	311.6	$	314.4	$	58.3	$	58.3

⁽¹⁾

Amounts in the Less than one year Eversource 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				WMECO
(Millions of Dollars)		As of September 30, 2015		As of December 31, 2014		As of September 30, 2015		As of December 31, 2014
Level 1:
	Mutual Funds and Equities	$	282.1	$	319.0	$	-	$	-
	Money Market Funds		30.7		24.9		8.0		4.3
Total Level 1		$	312.8	$	343.9	$	8.0	$	4.3
Level 2:
	U.S. Government Issued Debt Securities    (Agency and Treasury)	$	41.3	$	51.3	$	-	$	-
	Corporate Debt Securities		57.5		49.1		12.2		14.7
	Asset-Backed Debt Securities		27.9		54.1		7.6		14.5
	Municipal Bonds		123.9		116.3		10.3		13.0
	Other Fixed Income Securities		33.1		24.5		20.2		11.6
Total Level 2		$	283.7	$	295.3	$	50.3	$	53.8
Total Marketable Securities		$	596.5	$	639.2	$	58.3	$	58.1

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U.S. government issued debt securities are valued using market approaches that incorporate transactions for the same or similar bonds and adjustments for yields and maturity dates.  Corporate debt securities are valued using a market approach, utilizing recent trades of the same or similar instrument and also incorporating yield curves, credit spreads and specific bond terms and conditions.  Asset-backed debt securities include collateralized mortgage obligations, commercial mortgage backed securities, and securities collateralized by auto loans, credit card loans or receivables.  Asset-backed debt securities are valued using recent trades of similar instruments, prepayment assumptions, yield curves, issuance and maturity dates, and tranche information.  Municipal bonds are valued using a market approach that incorporates reported trades and benchmark yields.  Other fixed income securities are valued using pricing models, quoted prices of securities with similar characteristics, and discounted cash flows.

6.

SHORT-TERM AND LONG-TERM DEBT

Credit Agreements and Commercial Paper Programs:  On October 26, 2015, Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas amended and restated their joint five-year $1.45 billion revolving credit facility and extended the termination date to September 4, 2020.  The facility serves to backstop Eversource parent's $1.45 billion commercial paper program.  The commercial paper program allows Eversource parent to issue commercial paper as a form of short-term debt.  As of September 30, 2015 and December 31, 2014, Eversource parent had $757 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $693 million and $348.9 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively.  The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.41 percent and 0.43 percent, respectively.  As of September 30, 2015, there were intercompany loans from Eversource parent of $137.3 million to PSNH and $126.2 million to WMECO.  As of December 31, 2014, there were intercompany loans from Eversource parent of $133.4 million to CL&P, $90.5 million to PSNH and $21.4 million to WMECO.

On October 26, 2015, NSTAR Electric amended and restated its five-year $450 million revolving credit facility and extended the termination date to September 4, 2020.  The facility serves to backstop NSTAR Electric's $450 million commercial paper program.  As of September 30, 2015 and December 31, 2014, NSTAR Electric had $258.5 million and $302 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $191.5 million and $148 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively.  The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.18 percent and 0.27 percent, respectively.  

On June 16, 2015, the FERC granted authorization to allow CL&P and WMECO to incur total short-term borrowings up to a maximum of $600 million and $300 million, respectively, effective January 1, 2016 through December 31, 2017.

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

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

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

On May 20, 2015, CL&P issued $300 million of 4.15 percent 2015 Series A First and Refunding Mortgage Bonds due to mature in 2045.  The proceeds, net of issuance costs, were used to repay short-term borrowings.

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

On September 10, 2015, Yankee Gas issued $75 million of 3.35 percent 2015 Series M First Mortgage Bonds due to mature in 2025.  The proceeds, net of issuance costs, were used to repay short-term borrowings.

Long-Term Debt Issuance Authorization:  On April 3, 2015, the DPU authorized NSTAR Gas to issue up to $100 million in long-term debt for the period through December 31, 2015.

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7.

PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS

As of December 31, 2014, Eversource Service sponsored two defined benefit retirement plans that covered eligible employees, including employees of CL&P, NSTAR Electric, PSNH and WMECO.  Effective January 1, 2015, the two pension plans were merged into one plan, sponsored by Eversource Service.  As of December 31, 2014, Eversource Service also sponsored defined benefit postretirement plans that provide certain retiree benefits, primarily medical, dental and life insurance, to retiring employees that meet certain age and service eligibility requirements, including employees of CL&P, NSTAR Electric, PSNH and WMECO.  Effective January 1, 2015, the postretirement plans were merged into one plan, sponsored by Eversource Service.  

Terminated Vested Lump-Sum Payout Offer:  In August, 2015, Eversource made a total lump-sum payout of $149.5 million, which reduced the projected benefit obligation and Pension Plan assets by a corresponding amount.  Therefore, the lump-sum payment option had no impact on the net Accrued Pension Liability reflected on the Eversource, CL&P, PSNH and WMECO balance sheets as of September 30, 2015.  

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 is included in Operations and Maintenance 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.  Intercompany allocations are not included in the CL&P, NSTAR Electric, PSNH and WMECO net periodic benefit expense amounts.  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 and the corresponding capitalized portion, as these amounts are cash settled on a short-term basis.

	Pension and SERP				Pension and SERP
Eversource	For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2015 (1)		September 30, 2014		September 30, 2015 (1)		September 30, 2014
Service Cost	$	22.7	$	19.1	$	68.7	$	60.7
Interest Cost		56.9		56.4		170.3		169.5
Expected Return on Plan Assets		(83.9)		(77.7)		(252.1)		(233.1)
Actuarial Loss		36.5		31.7		111.9		96.5
Prior Service Cost		0.9		1.1		2.7		3.3
Total Net Periodic Benefit Expense	$	33.1	$	30.6	$	101.5	$	96.9
Capitalized Pension Expense	$	9.8	$	8.3	$	31.3	$	26.7
	PBOP				PBOP
Eversource	For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2015 (1)		September 30, 2014		September 30, 2015 (1)		September 30, 2014
Service Cost	$	4.1	$	3.1	$	10.3	$	9.3
Interest Cost		11.8		12.4		30.4		37.1
Expected Return on Plan Assets		(16.9)		(15.8)		(43.2)		(47.4)
Actuarial Loss		1.7		3.0		4.5		9.1
Prior Service Credit		(0.1)		(0.7)		(0.3)		(2.1)
Total Net Periodic Benefit Expense	$	0.6	$	2.0	$	1.7	$	6.0
Capitalized PBOP Expense/(Income)	$	-	$	1.1	$	0.1	$	1.9

	Pension and SERP
	For the Three Months Ended September 30, 2015								For the Three Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH (1)		WMECO		CL&P		Electric		PSNH		WMECO
Service Cost	$	6.2	$	3.7	$	3.1	$	1.0	$	5.0	$	3.0	$	2.3	$	0.8
Interest Cost		12.9		10.0		6.1		2.6		12.5		10.3		5.7		2.5
Expected Return on Plan Assets		(19.8)		(17.5)		(10.1)		(4.7)		(18.7)		(15.7)		(9.3)		(4.4)
Actuarial Loss		8.0		8.7		2.9		1.6		8.2		5.9		2.8		1.7
Prior Service Cost		0.4		-		0.1		0.1		0.4		-		0.1		0.1
Total Net Periodic Benefit Expense	$	7.7	$	4.9	$	2.1	$	0.6	$	7.4	$	3.5	$	1.6	$	0.7
Intercompany Allocations	$	5.8	$	3.4	$	1.6	$	1.1	$	6.5	$	2.9	$	1.8	$	1.2
Capitalized Pension Expense	$	4.7	$	2.7	$	0.8	$	0.5	$	4.3	$	2.6	$	0.7	$	0.6
	Pension and SERP
	For the Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH (1)		WMECO		CL&P		Electric		PSNH		WMECO
Service Cost	$	18.4	$	11.2	$	9.0	$	3.2	$	15.2	$	10.6	$	7.4	$	2.7
Interest Cost		38.4		30.2		18.1		7.8		38.1		31.0		18.0		7.8
Expected Return on Plan Assets		(59.1)		(52.5)		(30.3)		(14.2)		(56.7)		(47.3)		(28.8)		(13.5)
Actuarial Loss		24.2		27.0		8.8		4.8		25.5		17.6		8.9		5.2
Prior Service Cost		1.1		0.1		0.4		0.2		1.4		-		0.5		0.3
Total Net Periodic Benefit Expense	$	23.0	$	16.0	$	6.0	$	1.8	$	23.5	$	11.9	$	6.0	$	2.5
Intercompany Allocations	$	18.0	$	10.3	$	5.0	$	3.3	$	20.8	$	6.7	$	6.0	$	3.9
Capitalized Pension Expense	$	14.1	$	8.6	$	2.6	$	1.4	$	13.6	$	5.5	$	2.4	$	2.0

25

	PBOP
	For the Three Months Ended September 30, 2015								For the Three Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH (1)		WMECO	CL&P		Electric		PSNH		WMECO
Service Cost	$	0.5	$	1.3	$	0.3	$	0.1	$	0.6	$	0.8	$	0.3	$	0.1
Interest Cost		1.8		4.8		1.0		0.3		2.0		4.9		1.1		0.4
Expected Return on Plan Assets		(2.8)		(6.8)		(1.5)		(0.6)		(2.6)		(6.5)		(1.4)		(0.6)
Actuarial Loss/(Gain)		0.2		0.6		0.1		-		1.0		(0.1)		0.6		0.1
Prior Service Credit		-		(0.1)		-		-		-		(0.5)		-		-
Total Net Periodic Benefit Expense/(Income)	$	(0.3)	$	(0.2)	$	(0.1)	$	(0.2)	$	1.0	$	(1.4)	$	0.6	$	0.0
Intercompany Allocations	$	0.4	$	0.2	$	0.1	$	0.1	$	0.9	$	0.3	$	0.2	$	0.2
Capitalized PBOP Expense/(Income)	$	(0.1)	$	-	$	0.1	$	-	$	0.5	$	(0.5)	$	0.2	$	-
	PBOP
	For the Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
			NSTAR									NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH (1)		WMECO	CL&P			Electric	PSNH		WMECO
Service Cost	$	1.6	$	4.0	$	1.0	$	0.3	$	1.7	$	2.3	$	1.0	$	0.3
Interest Cost		5.4		14.2		2.9		1.1		6.0		14.6		3.2		1.3
Expected Return on Plan Assets		(8.3)		(20.5)		(4.4)		(1.9)		(7.9)		(19.5)		(4.1)		(1.7)
Actuarial Loss/(Gain)		0.5		1.8		0.4		-		3.2		(0.4)		1.7		0.3
Prior Service Credit		-		(0.1)		-		-		-		(1.4)		-		-
Total Net Periodic Benefit Expense/(Income)	$	(0.8)	$	(0.6)	$	(0.1)	$	(0.5)	$	3.0	$	(4.4)	$	1.8	$	0.2
Intercompany Allocations	$	1.4	$	0.7	$	0.3	$	0.3	$	3.1	$	0.4	$	0.8	$	0.6
Capitalized PBOP Expense/(Income)	$	(0.2)	$	(0.1)	$	0.2	$	(0.1)	$	1.5	$	(1.5)	$	0.6	$	0.1
(1) Amounts exclude approximately $0.8 million and $2.4 million for the three and nine months ended September 30, 2015, respectively, that represented amounts included in other deferred debits.

8.

COMMITMENTS AND CONTINGENCIES

A.

Environmental Matters

General:  Eversource, CL&P, NSTAR Electric, PSNH and WMECO are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment.  These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites.  Eversource, CL&P, NSTAR Electric, PSNH and WMECO have an active environmental auditing and training program and believe that they are substantially in compliance with all enacted laws and regulations.

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

	As of September 30, 2015				As of December 31, 2014
			Reserve				Reserve
	Number of Sites		(in millions)		Number of Sites		(in millions)
Eversource		64	$	46.9		65	$	43.3
CL&P		14		4.8		16		3.8
NSTAR Electric		14		2.2		13		1.1
PSNH		12		3.4		13		5.2
WMECO		4		0.6		4		0.5

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. The reserve balance related to these former MGP sites was $41 million and $38.8 million as of September 30, 2015 and December 31, 2014, respectively, and relates primarily to the natural gas business segment.

These estimates are subjective in nature as they take into consideration several different remediation options at each specific site. The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource, CL&P, NSTAR Electric, PSNH, or WMECO's responsibility or the extent of remediation required, recently enacted laws and regulations or a change in the estimates due to certain economic factors.

B.

Guarantees and Indemnifications

Eversource parent provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, in the form of guarantees in the normal course of business.  

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

Eversource parent issued a guaranty on behalf of its subsidiary, NPT, under which, beginning at the time the Northern Pass Transmission line goes into commercial operation, Eversource parent will guarantee the financial obligations of NPT under the TSA 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.  

26

Eversource parent has provided a guaranty of various indemnification and other obligations as a result of the April 13, 2015 sale of substantially all of the assets of E.S. Boulos Company, an unregulated electrical contractor based in Maine and indirect subsidiary of Eversource Energy.  Eversource parent has also guaranteed certain indemnification and other obligations as a result of the sales of former unregulated subsidiaries and the termination of an unregulated business, with maximum exposures either not specified or not material.  

Management does not anticipate a material impact to Net Income as a result of these various guarantees and indemnifications.  

The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, and guarantees to external parties, as of September 30, 2015:  

			Maximum Exposure
Company		Description	(in millions)		Expiration Dates
On behalf of subsidiaries:
	Various	Surety Bonds (1)	$	33.2	2015 - 2016
	Eversource Service and Rocky River Realty Company	Lease Payments for Vehicles and Real Estate	$	12.2	2019 and 2024
On behalf of external parties:
	Purchaser of E.S. Boulos Company and a bonding company	E.S. Boulos Company Indemnification	$	38.2	2016 and 2020
	Algonquin Gas Transmission, LLC	Access Northeast project
	(owner of Access Northeast assets)	capital contributions guarantee	$	206.0		2021

⁽¹⁾

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

C.

FERC ROE Complaints

Three separate complaints have been filed at FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (the "Complainants").  In the first complaint, filed in 2011, the Complainants alleged that the NETOs' base ROE of 11.14 percent that had been utilized since 2006 was unjust and unreasonable, asserted that the rate was excessive due to changes in the capital markets, and sought an order to reduce it prospectively from the date of the final FERC order and for the 15-month period beginning October 1, 2011 to December 31, 2012 (the "first complaint refund period").  In the second and third complaints, filed in 2012 and 2014, the Complainants challenged the NETOs' base ROE and sought refunds for the respective 15-month periods beginning December 27, 2012 and July 31, 2014.

In 2014, the FERC determined that the base ROE should be set at 10.57 percent for the first complaint refund period and that a utility's total or maximum ROE should not exceed the top of the new zone of reasonableness, which was set at 11.74 percent.  The FERC ordered the NETOs to provide refunds to customers for the first complaint refund period and set the new base ROE of 10.57 percent prospectively from October 16, 2014.  The NETOs and the Complainants sought rehearing from FERC.  In late 2014, the NETOs made a compliance filing, which was challenged by the Complainants, and the Company began refunding amounts from the first complaint period.

On March 3, 2015, FERC issued an order denying all issues raised on rehearing by the NETOs and Complainants in the first complaint.  The FERC order upheld the base ROE of 10.57 percent for the first complaint refund period and prospectively from October 16, 2014, and upheld that the utility's total ROE (the base ROEplus anyincentive adders) for the transmission assets to which the adder applies is capped at the top of the zone of reasonableness, which is currently set at 11.74 percent.  As a result of the clarifying information in the March 2015 order related to the application of the ROE cap, Eversource adjusted its reserve in the first quarter 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 to the D.C. Circuit Court of Appeals, which have been consolidated, and briefing is scheduled to be concluded in the second quarter of 2016.  A court decision is not expected until the second half of 2016.  

For the second and third complaint proceedings, hearings were held in late June and early July 2015 and briefs were filed in July and August 2015.  The state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced. The NETOs believe that the Complainants' positions are without merit, and the existing ROEs should be maintained.  The FERC ALJ’s initial recommendation is expected by December 30, 2015, and a final FERC order is expected in the third quarter of 2016.

D.

NSTAR Electric Basic Service Bad Debt Adder

On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006.  As a result of the DPU order, NSTAR Electric increased its regulatory assets and reduced operations and maintenance expense by $24.2 million in the first quarter of 2015, resulting in after-tax earnings of $14.5 million.  On May 5, 2015, NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers beginning July 1, 2015.  On June 24, 2015, the DPU delayed the effective date of NSTAR Electric’s proposed rate increase from July 1, 2015 to November 1, 2015 to allow for the DPU staff to review the reconciliations.  NSTAR Electric requested recovery from customers effective January 1, 2016 in briefs filed with the DPU in October 2015.  On October 27, 2015, the DPU delayed the effective date of the rate increase from November 1, 2015 to December 1, 2015 to allow the DPU staff additional time to review the reconciliations.  NSTAR Electric expects a decision from the DPU in the fourth quarter of 2015.

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

Upon completion of the divestiture process, all remaining stranded costs, including any remaining deferred equity return in excess of the $25 million that PSNH has agreed to forego, will be recovered via bonds that will be secured by a non-bypassable charge in rates billed to PSNH's customers.  

Implementation of the Agreement is subject to NHPUC approval, which is expected in early 2016.

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 September 30, 2015				As of December 31, 2014
Eversource	Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value
Preferred Stock Not   Subject to Mandatory Redemption	$	155.6	$	157.3	$	155.6	$	153.6
Long-Term Debt		8,986.4		9,419.6		8,851.6		9,451.2

	As of September 30, 2015
	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
Preferred Stock Not   Subject to Mandatory Redemption	$	116.2	$	115.4	$	43.0	$	41.9	$	-	$	-	$	-	$	-
Long-Term Debt		2,975.3		3,285.1		1,792.7		1,931.3		1,076.3		1,135.5		577.8		613.3
	As of December 31, 2014
	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
Preferred Stock Not   Subject to Mandatory Redemption	$	116.2	$	112.0	$	43.0	$	41.6	$	-	$	-	$	-	$	-
Long-Term Debt		2,842.0		3,214.5		1,797.4		1,993.5		1,076.3		1,137.9		628.5		689.4

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

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

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

28

10.

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

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

	For the Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
	Qualified		Unrealized						Qualified		Unrealized
	Cash Flow		Gains/(Losses)		Defined				Cash Flow		Gains on		Defined
Eversource	Hedging		on Marketable		Benefit				Hedging		Marketable		Benefit
(Millions of Dollars)	Instruments		Securities		Plans		Total		Instruments		Securities		Plans		Total
Balance as of Beginning of Period	$	(12.4)	$	0.7	$	(62.3)	$	(74.0)	$	(14.4)	$	0.4	$	(32.0)	$	(46.0)
OCI Before Reclassifications		-		(3.9)		(0.4)		(4.3)		-		0.2		1.2		1.4
Amounts Reclassified from AOCI		1.5		-		3.3		4.8		1.5		-		2.9		4.4
Net OCI		1.5		(3.9)		2.9		0.5		1.5		0.2		4.1		5.8
Balance as of End of Period	$	(10.9)	$	(3.2)	$	(59.4)	$	(73.5)	$	(12.9)	$	0.6	$	(27.9)	$	(40.2)

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, which are not material to their respective financial statements.  The amortization expense of actuarial gains and losses on the defined benefit plans is amortized from AOCI into Operations and Maintenance over the average future employee service period, and is reflected in amounts reclassified from AOCI.  The related tax effects of the reclassification adjustments are not material to the financial statements for the nine months ended September 30, 2015 and 2014.

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 and the respective per share par values:  

	Shares
			Authorized as of
	Per Share		September 30, 2015 and	Issued as of
	Par Value		December 31, 2014	September 30, 2015	December 31, 2014
Eversource	$	5	380,000,000	333,862,615	333,359,172
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 September 30, 2015 and December 31, 2014, there were 16,671,366 and 16,375,835 Eversource common shares held as treasury shares, respectively.  As of September 30, 2015 and December 31, 2014, Eversource common shares outstanding were 317,191,249 and 316,983,337, respectively.  In May 2015, the Company repurchased 532,521 treasury shares at a share price of $47.94.

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 September 30, 2015 and 2014 and $5.6 million for the nine months ended September 30, 2015 and 2014.  These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income.  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. For the three and nine months ended September 30, 2015, there were 5,894 and 1,965 antidilutive share awards excluded from the computation, respectively.  For the three and nine months ended September 30, 2014, 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 Nine Months Ended
(Millions of Dollars, except share information)		September 30, 2015		September 30, 2014		September 30, 2015		September 30, 2014
Net Income Attributable to Common Shareholders		$	235.9	$	234.6	$	696.7	$	597.9
Weighted Average Common Shares Outstanding:
	Basic		317,452,212		316,340,691		317,296,107		315,941,904
	Dilutive Effect		953,057		1,214,234		1,099,935		1,244,586
	Diluted		318,405,269		317,554,925		318,396,042		317,186,490
Basic EPS		$	0.74	$	0.74	$	2.20	$	1.89
Diluted EPS		$	0.74	$	0.74	$	2.19	$	1.89

29

RSUs and performance shares are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied.  The dilutive effect of unvested RSUs and performance shares is calculated using the treasury stock method.  Assumed proceeds of these units under the treasury stock method consist of the remaining compensation cost to be recognized and a theoretical tax benefit.  The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the units (the difference between the market value of the average units outstanding for the period, using the average market price during the period, and the grant date market value).  

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

14.

SEGMENT INFORMATION

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

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

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

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

Eversource's segment information is as follows:

	For the Three Months Ended September 30, 2015
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	1,543.7	$	106.2	$	270.4	$	211.6	$	(198.8)	$	1,933.1
Depreciation and Amortization		(84.5)		(17.5)		(42.4)		(7.1)		0.5		(151.0)
Other Operating Expenses		(1,140.8)		(92.7)		(78.3)		(199.6)		198.5		(1,312.9)
Operating Income		318.4		(4.0)		149.7		4.9		0.2		469.2
Interest Expense		(47.4)		(9.2)		(25.9)		(11.2)		1.2		(92.5)
Other Income, Net		1.9		(0.2)		3.8		241.9		(242.2)		5.2
Net Income Attributable to Common Shareholders	$	167.5	$	(3.7)	$	78.0	$	234.9	$	(240.8)	$	235.9
	For the Nine Months Ended September 30, 2015
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	4,686.5	$	799.6	$	787.2	$	655.2	$	(664.9)	$	6,263.6
Depreciation and Amortization		(342.1)		(53.4)		(122.6)		(21.5)		1.6		(538.0)
Other Operating Expenses		(3,535.7)		(631.5)		(225.5)		(619.4)		665.2		(4,346.9)
Operating Income		808.7		114.7		439.1		14.3		1.9		1,378.7
Interest Expense		(140.6)		(27.2)		(79.8)		(35.4)		3.4		(279.6)
Other Income, Net		9.6		(0.1)		11.9		777.0		(774.5)		23.9
Net Income Attributable to Common Shareholders	$	418.9	$	57.3	$	225.0	$	764.7	$	(769.2)	$	696.7
Cash Flows Used for Investments in Plant	$	506.5	$	120.0	$	493.9	$	56.9	$	-	$	1,177.3

	For the Three Months Ended September 30, 2014
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	1,502.6	$	109.2	$	262.5	$	211.2	$	(193.0)	$	1,892.5
Depreciation and Amortization		(71.7)		(16.4)		(37.4)		(13.8)		8.6		(130.7)
Other Operating Expenses		(1,141.5)		(98.4)		(74.2)		(192.4)		185.6		(1,320.9)
Operating Income/(Loss)		289.4		(5.6)		150.9		5.0		1.2		440.9
Interest Expense		(49.2)		(8.5)		(24.5)		(8.6)		1.0		(89.8)
Other Income, Net		9.3		0.1		2.7		226.4		(226.6)		11.9
Net Income/Loss) Attributable to   Common Shareholders	$	153.4	$	(9.9)	$	88.1	$	228.3	$	(225.3)	$	234.6

30

	For the Nine Months Ended September 30, 2014
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	4,350.4	$	737.5	$	721.4	$	568.1	$	(516.7)	$	5,860.7
Depreciation and Amortization		(309.9)		(51.1)		(111.4)		(28.3)		12.7		(488.0)
Other Operating Expenses		(3,343.9)		(586.2)		(211.5)		(534.1)		505.6		(4,170.1)
Operating Income		696.6		100.2		398.5		5.7		1.6		1,202.6
Interest Expense		(143.8)		(25.6)		(78.8)		(27.2)		3.2		(272.2)
Other Income, Net		13.6		0.2		6.9		657.9		(659.5)		19.1
Net Income Attributable to Common Shareholders	$	349.1	$	44.2	$	206.8	$	653.4	$	(655.6)	$	597.9
Cash Flows Used for Investments in Plant	$	480.1	$	120.6	$	469.9	$	46.9	$	-	$	1,117.5
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 September 30, 2015	$	17,836.8	$	2,986.0	$	7,773.7	$	12,750.0	$	(11,300.5)	$	30,046.0
As of December 31, 2014		17,563.4		3,030.9		7,625.6		12,682.5		(11,124.4)		29,778.0

31

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 First and Second Quarter 2015 Quarterly Reports on Form 10-Q, and the 2014 Annual Report on Form 10-K.  References in this Form 10-Q to "Eversource," the "Company," "we," "us," and "our" refer to Eversource 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 discussion below also includes non-GAAP financial measures referencing our third quarter and first nine months of 2015 and 2014 earnings and EPS excluding certain integration costs incurred by Eversource parent and our regulated companies.  We use these non-GAAP financial measures to evaluate and to provide details of earnings by business and to more fully compare and explain our third quarter and first nine months of 2015 and 2014 results without including the impact of these items.  Due to the nature and significance of these items on Net Income Attributable to Common Shareholders, we believe that the non-GAAP presentation is more representative of our financial performance and provides additional and useful information to readers of this report in analyzing historical and future performance by business.  These non-GAAP financial measures should not be considered as an alternative to reported Net Income Attributable to Common Shareholders or EPS determined in accordance with GAAP as an indicator of operating performance.

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

Forward-Looking Statements:  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 and economic conditions, including their impact on interest rates, bad debt expense, and demand for our products and services, which could include disruptive technology related to our current or future business model,

·

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 Quarterly Report on Form 10-Q and in Eversource's 2014 combined Annual Report on Form 10-K. This Quarterly Report on Form 10-Q and Eversource's 2014 combined Annual Report on Form 10-K also describes material contingencies and critical accounting policies in the

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accompanying Management's Discussion and Analysis of Financial Condition and Results of Operations and Combined Notes to Condensed Consolidated Financial Statements (Unaudited).  We encourage you to review these items.

Financial Condition and Business Analysis

Executive Summary

Results:

·

We earned $235.9 million, or $0.74 per share, in the third quarter of 2015 and $696.7 million, or $2.19 per share, in the first nine months of 2015, compared with $234.6 million, or $0.74 per share, in the third quarter of 2014 and $597.9 million, or $1.89 per share, in the first nine months of 2014.  Excluding integration costs, we earned $237.6 million, or $0.75 per share, in the third quarter of 2015 and $704.5 million, or $2.21 per share, in the first nine months of 2015, compared with $237.6 million, or $0.75 per share, in the third quarter of 2014 and $611.3 million, or $1.93 per share, in the first nine months of 2014.

·

Our electric distribution segment, which includes generation, earned $167.7 million, or $0.53 per share, in the third quarter of 2015 and $419.8 million, or $1.32 per share, in the first nine months of 2015, compared with earnings of $153.4 million, or $0.48 per share, in the third quarter of 2014 and $349.1 million, or $1.10 per share, in the first nine months of 2014.  Our transmission segment earned $78 million, or $0.24 per share, in the third quarter of 2015 and $225 million, or $0.70 per share, in the first nine months of 2015, compared with $88.1 million, or $0.28 per share, in the third quarter of 2014 and $206.8 million, or $0.65 per share, in the first nine months of 2014.  Our natural gas distribution segment had a net loss of $3.5 million, or $0.01 per share, in the third quarter of 2015 and earnings of $57.5 million, or $0.18 per share, in the first nine months of 2015, compared with a net loss of $9.9 million, or $0.03 per share, in the third quarter of 2014 and earnings of $44.2 million, or $0.14 per share, in the first nine months of 2014.  These third quarter and first nine months 2015 results exclude $0.4 million and $1.1 million, respectively, of after-tax integration costs.  

·

Eversource parent and other companies had a net loss of $4.6 million, or $0.01 per share, in the third quarter of 2015 and earnings of $2.2 million, or $0.01 per share, in the first nine months of 2015, compared with earnings of $6 million, or $0.02 per share, and $11.2 million, or $0.04 per share, in the third quarter and the first nine months of 2014, respectively.  Third quarter and the first nine months of 2015 results exclude $1.3 million, or $0.01 per share, and $6.7 million, or $0.02 per share, respectively, of after-tax integration costs.  Third quarter and the first nine months of 2014 results exclude $3 million, or $0.01 per share, and $13.4 million, or $0.04 per share, respectively, of after-tax integration costs.  

Liquidity:

·

Cash flows provided by operating activities totaled $1.3 billion in the first nine months of 2015, compared with $1.4 billion in the first nine months of 2014.  Investments in property, plant and equipment totaled $1.2 billion in the first nine months of 2015, compared with $1.1 billion in the first nine months of 2014.  Cash and cash equivalents totaled $35.8 million as of September 30, 2015, compared with $38.7 million as of December 31, 2014.

·

On September 1, 2015, our Board of Trustees approved a common share dividend payment of $0.4175 per share, which was paid on September 30, 2015 to shareholders of record as of September 14, 2015.

Legislative, Regulatory, Policy and Other Items:   

·

On July 21, 2015, the DOE issued the draft Environmental Impact Statement (EIS) for Northern Pass representing a key milestone in the permitting process.  On August 18, 2015, the revised route was announced including burying 52 miles of the route underground in and around the White Mountain National Forest region.  As a result, the NPT project estimate has increased from $1.4 billion to $1.6 billion.  On October 19, 2015, NPT filed the New Hampshire Site Evaluation Committee (NH SEC) application.  

Overview

Consolidated:  A summary of our earnings by business, which also reconciles the non-GAAP financial measures of consolidated non-GAAP earnings and EPS, as well as EPS by business, to the most directly comparable GAAP measures of consolidated Net Income Attributable to Common Shareholders and diluted EPS, for the third quarter and first nine months of 2015 and 2014, is as follows:

	For the Three Months Ended September 30,								For the Nine Months Ended September 30,
(Millions of Dollars, Except	2015				2014				2015				2014
Per Share Amounts)	Amount		Per Share		Amount		Per Share		Amount		Per Share		Amount		Per Share
Net Income Attributable to   Common Shareholders (GAAP)	$	235.9	$	0.74	$	234.6	$	0.74	$	696.7	$	2.19	$	597.9	$	1.89
Regulated Companies	$	242.2	$	0.76	$	231.6	$	0.73	$	702.3	$	2.20	$	600.1	$	1.89
ES Parent and Other Companies		(4.6)		(0.01)		6.0		0.02		2.2		0.01		11.2		0.04
Non-GAAP Earnings		237.6		0.75		237.6		0.75		704.5		2.21		611.3		1.93
Integration Costs (after-tax)		(1.7)		(0.01)		(3.0)		(0.01)		(7.8)		(0.02)		(13.4)		(0.04)
Net Income Attributable to   Common Shareholders (GAAP)	$	235.9	$	0.74	$	234.6	$	0.74	$	696.7	$	2.19	$	597.9	$	1.89

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The 2015 and 2014 integration costs are costs associated with our branding efforts and severance costs.  The branding costs are not recoverable in rates charged to our customers.

Regulated Companies:  Our Regulated companies consist of the electric distribution, transmission, and natural gas distribution segments.  Generation activities of PSNH and WMECO are included in our electric distribution segment.  A summary of our segment earnings and EPS for the third quarter and first nine months of 2015 and 2014 is as follows:

	For the Three Months Ended September 30,								For the Nine Months Ended September 30,
(Millions of Dollars, Except	2015				2014				2015				2014
Per Share Amounts)	Amount		Per Share		Amount		Per Share		Amount		Per Share		Amount		Per Share
Electric Distribution	$	167.7	$	0.53	$	153.4	$	0.48	$	419.8	$	1.32	$	349.1	$	1.10
Transmission		78.0		0.24		88.1		0.28		225.0		0.70		206.8		0.65
Natural Gas Distribution		(3.5)		(0.01)		(9.9)		(0.03)		57.5		0.18		44.2		0.14
Non-GAAP Earnings		242.2		0.76		231.6		0.73		702.3		2.20		600.1		1.89
Integration Costs (after-tax)		(0.4)		-		-		-		(1.1)		-		-		-
Net Income - Regulated Companies	$	241.8	$	0.76	$	231.6	$	0.73	$	701.2	$	2.20	$	600.1	$	1.89

The third quarter and first nine months 2015 Regulated companies' integration costs include costs incurred for severance in connection with reorganizational and cost saving initiatives.

Excluding integration costs, our electric distribution segment earnings increased $14.3 million in the third quarter of 2015, as compared to the third quarter of 2014, due primarily to the impact of the December 1, 2014 CL&P base distribution rate increase, higher retail sales volumes at NSTAR Electric and PSNH, an increase in the recovery of LBR at NSTAR Electric related to 2015 energy efficiency programs, an increase in CL&P’s revenues through an adjustment to rate base associated with the accumulated deferred income taxes (ADIT) order, and a decrease in operations and maintenance costs primarily attributable to lower employee-related expenses.  Partially offsetting these favorable earnings impacts were higher depreciation expense and higher property taxes.

Excluding integration costs, our electric distribution segment earnings increased $70.7 million in the first nine months of 2015, as compared to the first nine months of 2014, due primarily to the impact of the December 1, 2014 CL&P base distribution rate increase, the $27.5 million favorable earnings impact related to the resolution of NSTAR Electric’s basic service bad debt adder, the settlement with the Massachusetts Attorney General on eleven open dockets covering the CPSL program filings and the recovery of LBR related to 2009 through 2011 energy efficiency programs at NSTAR Electric, a decrease in operations and maintenance costs primarily attributable to lower employee-related expenses, an increase in the recovery of LBR at NSTAR Electric related to 2015 energy efficiency programs, higher retail sales volumes at NSTAR Electric and PSNH, and the impact of increased CL&P revenues from the ADIT order.  Partially offsetting these favorable earnings impacts were higher depreciation expense, higher property taxes and a $5 million contribution to create a clean energy fund in connection with the PSNH divestiture agreement.

Our transmission segment earnings decreased $10.1 million in the third quarter of 2015, as compared to the third quarter of 2014, due primarily to the absence of favorable state income tax benefits recorded in the third quarter of 2014, partially offset by higher transmission rate base as a result of an increased investment in our transmission infrastructure.

Our transmission segment earnings increased $18.2 million in the first nine months of 2015, as compared to the first nine months of 2014, due primarily to the result of lower reserves associated with the FERC ROE complaint proceedings of $12.4 million recorded in 2015, as compared to $32.1 million recorded in 2014, and a higher transmission rate base as a result of an increased investment in our transmission infrastructure.  These favorable earnings impacts were partially offset by the absence of favorable state income tax benefits recorded in 2014.

Our natural gas distribution segment results improved by $6.4 million in the third quarter of 2015, as compared to the third quarter of 2014, due primarily to favorable income tax benefits recorded in the third quarter of 2015, partially offset by higher depreciation expense and higher property taxes.

Our natural gas distribution segment earnings increased $13.3 million in the first nine months of 2015, as compared to the first nine months of 2014, due primarily to higher firm natural gas sales volumes and peak demand revenues resulting from colder weather in the first quarter of 2015, as compared to the first quarter of 2014, additional natural gas heating customers, a decrease in operations and maintenance costs primarily attributable to lower employee-related expenses, and favorable income tax benefits recorded in 2015.  These favorable earnings impacts were partially offset by higher depreciation expense and higher property taxes.

Eversource Parent and Other Companies:  Excluding the impact of integration costs, Eversource parent and other companies had a net loss of $4.6 million and earnings of $2.2 million in the third quarter and first nine months of 2015, respectively, compared with earnings of $6 million and $11.2 million in the third quarter and first nine months of 2014, respectively.  The earnings decrease in the first nine months of 2015 was due primarily to a higher effective tax rate at Eversource parent in 2015, as compared to 2014, higher interest expense at Eversource parent as a result of new debt issuances in January 2015, a bad debt charge recorded in the third quarter of 2015 at Eversource's unregulated business, and the absence of earnings from Eversource's unregulated electrical contracting business, which was sold in April 2015.

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Electric and Natural Gas Sales Volumes:  A summary of our retail electric GWh sales volumes and percentage changes, as well as percentage changes in CL&P, NSTAR Electric, PSNH and WMECO retail electric GWh sales volumes, is as follows:

	For the Three Months Ended September 30, 2015 Compared to 2014
	Eversource			CL&P	NSTAR Electric	PSNH	WMECO
	Sales Volumes (GWh)		Percentage	Percentage	Percentage	Percentage	Percentage
Electric	2015	2014	Increase/(Decrease)	Increase/(Decrease)	Increase/(Decrease)	Increase	Increase
Residential	6,077	5,656	7.4  %	8.9  %	6.7  %	5.3  %	5.8  %
Commercial	7,613	7,382	3.1  %	3.2  %	3.0  %	3.3  %	3.5  %
Industrial	1,516	1,517	(0.1)%	(0.2)%	(2.3)%	1.2  %	2.3  %
Total	15,206	14,555	4.5  %	5.4  %	3.9  %	3.7  %	4.2  %

	For the Nine Months Ended September 30, 2015 Compared to 2014
	Eversource			CL&P	NSTAR Electric	PSNH	WMECO
	Sales Volumes (GWh)		Percentage	Percentage	Percentage	Percentage	Percentage
Electric	2015	2014	Increase/(Decrease)	Increase/(Decrease)	Increase/(Decrease)	Increase/(Decrease)	Increase/(Decrease)
Residential	16,814	16,306	3.1  %	3.7  %	3.0  %	2.4  %	1.2  %
Commercial	21,139	20,838	1.4  %	1.0  %	1.8  %	1.3  %	1.4  %
Industrial	4,221	4,295	(1.7)%	(1.3)%	(3.1)%	(1.2)%	(1.6)%
Total	42,174	41,439	1.8  %	2.0  %	1.9  %	1.3  %	0.8  %

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

	For the Three Months Ended			For the Nine Months Ended
	September 30, 2015 Compared to 2014			September 30, 2015 Compared to 2014
	Sales (million cubic feet)		Percentage	Sales (million cubic feet)		Percentage
Firm Natural Gas	2015	2014	Decrease	2015	2014	Increase/(Decrease)
Residential	2,485	2,487	(0.1)%	29,101	27,468	5.9  %
Commercial	4,502	4,565	(1.4)%	32,889	31,032	6.0  %
Industrial	4,150	4,276	(3.0)%	16,499	16,669	(1.0)%
Total	11,137	11,328	(1.7)%	78,489	75,169	4.4  %
Total, Net of Special Contracts (1)	10,022	10,200	(1.7)%	75,106	71,645	4.8  %

⁽¹⁾

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

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

For CL&P (effective December 1, 2014) and WMECO, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission approved revenue decoupling mechanisms.  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 to pre-established levels of baseline distribution delivery service revenues.  Any difference between the allowed level of distribution revenue and the actual amount incurred during a 12-month period is adjusted through rates in the following period.  Prior to December 1, 2014, CL&P earned LBR related to reductions in sales volume as a result of successful energy efficiency programs.  LBR was recovered from retail customers through the FMCC.  Effective December 1, 2014, CL&P no longer earns LBR due to its revenue decoupling mechanism.  NSTAR Electric continues to recognize LBR through December 31, 2015 in accordance with the 2012 DPU-approved comprehensive merger settlement agreement with the Massachusetts Attorney General.  For the first nine months of 2015 and 2014, NSTAR Electric recognized LBR of $46.7 million and $28.2 million, respectively.  NSTAR Electric has filed for approval of a three-year energy efficiency plan with the DPU, which includes recovery of LBR until it is operating under a decoupled rate structure.  For further information, see "Regulatory Developments and Rate Matters - Massachusetts - Energy Efficiency Plan" in this Management's Discussion and Analysis of Financial Conditions and Results of Operations.

For the third quarter of 2015, our consolidated retail electric sales volumes were higher, as compared to the same period in 2014, due primarily to warmer weather in 2015.  Cooling degree days in the third quarter of 2015 were 25 percent higher in Connecticut and western Massachusetts, 29 percent higher in the Boston metropolitan area, and 59 percent higher in New Hampshire, as compared to the third quarter of 2014.  Weather-normalized Eversource consolidated retail electric sales volumes increased 1.6 percent in the third quarter of 2015, as compared to the third quarter of 2014.  The increase was due primarily to improved economic conditions, partially offset by an increase in conservation efforts primarily by our residential customers, resulting from company-sponsored energy efficiency programs.  

For the first nine months of 2015, our consolidated retail electric sales volumes were higher, as compared to the same period in 2014, due primarily to the impact of colder winter weather experienced in the first quarter of 2015 and the warmer weather in the third quarter of 2015 throughout our service territories.  The first nine months of 2015 heating degree days were 1.2 percent higher in Connecticut and western Massachusetts, 6.6 percent higher in the Boston metropolitan area, and 2.2 percent lower in New Hampshire, as compared to the first nine months of 2014.  Weather-normalized Eversource consolidated retail electric sales volumes were relatively unchanged in the first nine months of 2015, as compared to the first nine months of 2014.  Improved economic conditions were offset by an increase in conservation efforts primarily by our residential customers, resulting from company-sponsored energy efficiency programs.

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Our firm natural gas sales are subject to many of the same influences as our retail electric sales.  In addition, they have benefited from customer growth in both of our natural gas distribution companies.  In the third quarter and first nine months of 2015, consolidated firm natural gas sales volumes were lower as compared to the third quarter of 2014, and higher as compared to the first nine months of 2014.  Third quarter 2015 firm natural gas sales volumes were negatively impacted by warmer weather when compared to the third quarter of 2014.  First nine months 2015 firm natural gas sales volumes were favorably impacted by colder winter weather experienced throughout our natural gas service territories in the first quarter of 2015 compared to the same period in 2014.  The third quarter and first nine months of 2015 weather-normalized Eversource consolidated firm natural gas sales volumes increased compared to the same periods in 2014 due primarily to residential and commercial customer growth and improved economic conditions, partially offset by customer conservation efforts resulting from company-sponsored energy efficiency programs.  

Liquidity

Consolidated:  Cash and cash equivalents totaled $35.8 million as of September 30, 2015, compared with $38.7 million as of December 31, 2014.

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

On September 2, 2015, NSTAR Gas priced $100 million of 4.35 percent Series O First Mortgage Bonds due to mature in 2045.  The transaction is scheduled to close on December 8, 2015.

On September 10, 2015, Yankee Gas issued $75 million of 3.35 percent 2015 Series M First Mortgage Bonds due to mature in 2025.  The proceeds, net of issuance costs, were used to repay short-term borrowings.

On October 26, 2015, Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas amended and restated their joint five-year $1.45 billion revolving credit facility and extended the termination date to September 4, 2020.  The facility serves to backstop Eversource parent's $1.45 billion commercial paper program.  The commercial paper program allows Eversource parent to issue commercial paper as a form of short-term debt.  As of September 30, 2015 and December 31, 2014, Eversource parent had $757 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $693 million and $348.9 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively.  The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.41 percent and 0.43 percent, respectively.  As of September 30, 2015, there were intercompany loans from Eversource parent of $137.3 million to PSNH and $126.2 million to WMECO.  As of December 31, 2014, there were intercompany loans from Eversource parent of $133.4 million to CL&P, $90.5 million to PSNH and $21.4 million to WMECO.

On October 26, 2015, NSTAR Electric amended and restated its five-year $450 million revolving credit facility and extended the termination date to September 4, 2020.  The facility serves to backstop NSTAR Electric's $450 million commercial paper program.  As of September 30, 2015 and December 31, 2014, NSTAR Electric had $258.5 million and $302 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $191.5 million and $148 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively.  The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.18 percent and 0.27 percent, respectively.  

Cash flows provided by operating activities totaled $1.3 billion in the first nine months of 2015, compared with $1.4 billion in the first nine months of 2014.  The decrease in operating cash flows was due primarily to the timing of regulatory recoveries resulting from both increased purchased power and congestion costs at NSTAR Electric, WMECO and CL&P, and the timing of collections and payments related to our working capital items, including accounts receivable and accounts payable.  Accounts receivable increased due primarily to increases in both CL&P’s and NSTAR Electric’s basic service rates effective January 1, 2015, and the increase in CL&P's base distribution rates effective December 1, 2014.  Also contributing to the decrease in operating cash flows was the absence of the receipt of approximately $132 million in DOE Phase II Damages proceeds received in 2014 from the Yankee Companies and an increase of approximately $88 million in Pension and PBOP Plan cash contributions in the first nine months of 2015, as compared to the same period in 2014.  Partially offsetting these unfavorable cash flow impacts were net income tax refunds of approximately $105 million received in the first nine months of 2015 primarily related to the extension of the accelerated depreciation deduction, as compared to income tax payments of approximately $256 million in the first nine months of 2014.  

In the first nine months of 2015, we paid cash dividends on common shares of $397.4 million, compared with $356.1 million in the first nine months of 2014.  On September 1, 2015, our Board of Trustees approved a common share dividend payment of $0.4175 per share, which was paid on September 30, 2015 to shareholders of record as of September 14, 2015.

In the first nine months of 2015, CL&P, NSTAR Electric, PSNH, and WMECO paid $147 million, $148.5 million, $79.5 million, and $27.9 million, respectively, in common stock dividends to Eversourceparent.  

Investments in Property, Plant and Equipment on the statements of cash flows do not include amounts incurred on capital projects but not yet paid, cost of removal, AFUDC related to equity funds, and the capitalized portions of pension expense.  In the first nine months of 2015, investments for Eversource, CL&P, NSTAR Electric, PSNH, and WMECO were $1.2 billion, $359.3 million, $314.1 million, $209.5 million, and $93.7 million, respectively.  

Business Development and Capital Expenditures

Our consolidated capital expenditures, including amounts incurred but not paid, cost of removal, AFUDC, and the capitalized portions of pension expense (all of which are non-cash factors), totaled $1.3 billion in the first nine months of 2015, compared with $1.1 billion in the first nine months of 2014.  These amounts included $58.6 million and $40.9 million in the first nine months of 2015 and 2014, respectively, related to information technology and facilities upgrades and enhancements, primarily at Eversource Service and The Rocky River Realty Company.

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Natural Gas Transmission Business:  

Access Northeast:  Access Northeast is a natural gas pipeline and storage project being developed jointly by Eversource, Spectra Energy Corp and National Grid.  Access Northeast will enhance the Algonquin and Maritimes & Northeast pipeline systems using existing routes and will include two new LNG storage tanks and liquefaction and vaporization facilities in Acushnet, Massachusetts that will be connected to the Algonquin gas pipeline.  The project is expected to be capable of delivering approximately one billion cubic feet of additional natural gas per day to New England.  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 project is subject to FERC approval, and the total project 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.  On November 3, 2015, a request was filed for FERC approval to initiate the pre-filing review process for Access Northeast.  Upon completion of the pre-filing review, a certificate application will be filed with the FERC.

Electric Transmission Business:  Our consolidated electric transmission business capital expenditures increased by $62.6 million in the first nine months of 2015, as compared to the first nine months of 2014.  A summary of transmission capital expenditures by company is as follows:  

	For the Nine Months Ended September 30,
(Millions of Dollars)	2015		2014
CL&P	$	146.9	$	201.5
NSTAR Electric		158.9		111.1
PSNH		115.2		76.9
WMECO		72.9		50.1
NPT		27.7		19.4
Total Electric Transmission Segment	$	521.6	$	459.0

NEEWS:  The Interstate Reliability Project (IRP) includes CL&P's construction of an approximately 40-mile, 345-kV overhead line from Lebanon, Connecticut to the Connecticut-Rhode Island border in Thompson, Connecticut where it will connect to transmission enhancements being constructed by National Grid in Rhode Island and Massachusetts.  Construction has been underway in all three states since March 2014.  Eversource's portion of the cost is estimated to be $218 million, and we expect to complete IRP by the end of 2015.  As of September 30, 2015, CL&P had placed $190.7 million in service with minimal remaining close-out activities continuing throughout the remainder of 2015.

Through September 30, 2015, CL&P and WMECO capitalized $378.2 million and $566.9 million, respectively, in costs associated with NEEWS.  

GHCC:  The Greater Hartford Central Connecticut (GHCC) solutions are comprised of 27 projects and are expected to cost approximately $350 million and be placed in service from 2016 through 2018.  Through September 2015, we have filed siting applications for five projects of which all have been approved by the Connecticut Siting Council, allowing us to commence construction on those projects in 2015.  Additional siting applications are expected to be filed through the remainder of 2015 and 2016.  All GHCC projects are expected to be completed in late 2018.  As of September 30, 2015, CL&P had capitalized $25.2 million in costs associated with GHCC.  

Northern Pass:  Northern Pass is Eversource's planned HVDC transmission line from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire.  Northern Pass will interconnect at the Québec-New Hampshire border with a planned HQ HVDC transmission line.  On July 21, 2015, the DOE issued the draft Environmental Impact Statement (EIS) for Northern Pass representing a key milestone in the permitting process.  On August 18, 2015, the revised route was announced including burying 52 miles of the route underground in and around the White Mountain National Forest region.  As a result, the NPT project estimate has increased from $1.4 billion to $1.6 billion.  In response to requests by the New Hampshire congressional delegation, the DOE announced that it would issue a supplement to the draft EIS, delaying public hearings to allow the DOE to receive comments through the end of 2015.  On October 19, 2015, NPT filed the New Hampshire Site Evaluation Committee (NH SEC) application.  The project is expected to be operational in the first half of 2019.

We expect NPT to participate in the New England Clean Energy RFP process.  For further information on the RFP process, see "Regulatory Developments and Rate Matters – General – Clean Energy Draft RFP" in this Management's Discussion and Analysis of Financial Conditions and Results of Operations.

On August 18, 2015, NPT also announced the Forward NH Plan, which includes a $200 million initiative to allocate funds to projects associated with economic development, community betterment, and clean energy innovations to benefit the state of New Hampshire.  This initiative is contingent upon the Northern Pass transmission line going into commercial operation.  

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

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Distribution Business:  A summary of distribution capital expenditures by company for the first nine months of 2015 and 2014 is as follows:

	For the Nine Months Ended September 30,
(Millions of Dollars)	2015		2014
CL&P:
Basic Business	$	87.8	$	70.2
Aging Infrastructure		120.0		81.1
Load Growth		29.6		49.7
Total CL&P		237.4		201.0
NSTAR Electric:
Basic Business		75.2		75.4
Aging Infrastructure		69.8		76.0
Load Growth		30.5		25.8
Total NSTAR Electric		175.5		177.2
PSNH:
Basic Business		37.8		33.1
Aging Infrastructure		33.9		24.2
Load Growth		15.8		21.4
Total PSNH		87.5		78.7
WMECO:
Basic Business		12.2		6.2
Aging Infrastructure		13.5		10.2
Load Growth		4.6		3.6
Total WMECO		30.3		20.0
Total - Electric Distribution (excluding Generation)		530.7		476.9
PSNH Generation		15.9		11.3
WMECO Generation		-		7.5
Natural Gas		132.8		138.9
Total Electric and Natural Gas Distribution Segment	$	679.4	$	634.6

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.  

FERC Regulatory Issues

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

On March 3, 2015, FERC issued an order denying all issues raised on rehearing by the NETOs and Complainants in the first complaint.  The FERC order upheld the base ROE of 10.57 percent for the first complaint refund period and prospectively from October 16, 2014, and upheld that the utility's total ROE (the base ROEplus anyincentive adders) for the transmission assets to which the adder applies is capped at the top of the zone of reasonableness, which is currently set at 11.74 percent.  As a result of the clarifying information in the March 2015 order related to the application of the ROE cap, Eversource adjusted its reserve in the first quarter 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.  The NETOs and Complainants have filed appeals to the D.C. Circuit Court of Appeals, which have been consolidated, and briefing is scheduled to be concluded in the second quarter of 2016.  A court decision is not expected until the second half of 2016.  

For the second and third complaint proceedings, hearings were held in late June and early July 2015 and briefs were filed in July and August 2015.  The state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced.  The NETOs believe that the Complainants' positions are without merit, and the existing ROEs should be maintained.  The FERC ALJ’s initial recommendation is expected by December 30, 2015, and a final FERC order is expected in the third quarter of 2016.

Regulatory Developments and Rate Matters

The Regulated companies' distribution rates are set by their respective state regulatory commissions, and their tariffs include mechanisms for periodically adjusting their rates for the recovery of specific incurred costs.  Other than as described below, for the first nine months of 2015, 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 2014 Annual Report on Form 10-K.

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General:

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

The DPU and the Rhode Island Public Utilities Commission (PUC) approved the draft RFP that was jointly submitted by certain EDCs.  The draft RFP encompassed the timetable and method for the solicitation and execution of any associated long-term contracts.  On August 31, 2015, the DEEP issued a notice of proceeding on the Connecticut portion of the draft RFP and accepted public comment through September 30, 2015.  We expect the DEEP and the Massachusetts and Rhode Island EDCs to issue the RFP to a wide range of potentially interested bidders shortly after the DEEP approves the RFP.  We expect the potential bidders will submit proposals within 75 days from the date that the RFPs are issued and that contractual agreements will be submitted for approval to the respective state regulators in 2016.

New England Natural Gas Pipeline Capacity:  In 2014, the six New England states began to explore ways to address and mitigate winter natural gas price spikes and the associated impact on electric power supply costs attributable to winter pipeline capacity constraints.  In Massachusetts, the DPU issued an order on October 2, 2015 determining that it has authority to allow EDCs to contract for natural gas pipeline capacity.  On October 23, 2015, Eversource and National Grid issued a natural gas pipeline capacity RFP in Massachusetts with bids due November 13, 2015.  On September 15, 2015, the NHPUC staff issued a report concluding that the NHPUC could approve contracts between pipelines and EDCs if they were shown to reduce electricity costs and be in the public interest.  In Connecticut, the DEEP expects to provide an opportunity for public comment on a natural gas pipeline capacity RFP in the fourth quarter of 2015.  While all New England states are considering how to address these pipeline constraints, it is unclear whether additional New England states will join Massachusetts and Connecticut in holding RFPs for natural gas pipeline capacity.

Electric and Natural Gas Residential Customer Rates:  Effective July 1, 2015, as approved by the respective state regulatory commission, each Eversource electric and natural gas operating company’s total average residential customer billing rate decreased.  For those residential customers who purchase generation supply from the respective electric utility company, the average bill decreased by 18 percent at CL&P, 20 percent at NSTAR Electric, 7 percent at PSNH, and 18 percent at WMECO and the average natural gas residential customer’s bill decreased by 10 percent at Yankee Gas and 20 percent at NSTAR Gas.  The decrease was due primarily to a decrease in the electric generation and natural gas supply rates.  Supply rates consist of costs that are recovered from customers in rates through regulatory commission-approved cost tracking mechanisms and therefore have no impact on earnings.

Connecticut:

CL&P Distribution Rates: On December 17, 2014, PURA granted a re-opener request to CL&P’s base distribution rate application for further review of the appropriate balance of ADIT utilized in the calculation of rate base.  On July 2, 2015, PURA issued a final order that approved a settlement agreement filed on May 19, 2015 between CL&P and the PURA Prosecutorial Staff.  The order allows for an increase to rate base of approximately $163 million associated with ADIT, including a regulatory asset to recover the incremental revenue requirement for the period December 1, 2014 through November 30, 2015 over a subsequent two-year period.  The rate base increase provided an increase to total allowed annual revenue requirements of $18.4 million beginning December 1, 2014.  Of that amount, $15.3 million has been recorded as a regulatory asset through September 30, 2015, with a corresponding increase in Operating Revenues.  The remaining $3.1 million will be recorded in the fourth quarter of 2015.  The aggregate amount will be collected from customers in rates over a 24-month period commencing on December 1, 2015.

Conservation and Load Management Plan:  On October 1, 2015, CL&P and Yankee Gas filed for approval of the three-year electric and natural gas C&LM plan with the DEEP, which was jointly developed with other Connecticut EDCs and natural gas distribution companies.  The C&LM plan, which covers the years 2016 through 2018, was built upon the continued success and momentum of the previous C&LM plans.  The C&LM plan includes performance incentives totaling $24 million over the three year period related to proposed savings goals for CL&P and Yankee Gas.  

Massachusetts:

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

NSTAR Electric Basic Service Bad Debt Adder:  On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006.  As a result of the DPU order, NSTAR Electric increased its regulatory assets and reduced operations and maintenance expense by $24.2 million in the first quarter of 2015, resulting in after-tax earnings of $14.5 million.  On May 5, 2015, NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers beginning July 1, 2015.  On June 24, 2015, the DPU delayed the effective date of NSTAR Electric’s proposed rate increase from July 1, 2015 to November 1, 2015 to allow for the DPU staff to review the reconciliations.  NSTAR Electric requested recovery from customers effective January 1, 2016 in briefs filed with the DPU in October 2015.  On October 27, 2015, the DPU delayed the effective date of the rate increase from November 1, 2015 to

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December 1, 2015 to allow the DPU staff additional time to review the reconciliations.  We expect a decision from the DPU in the fourth quarter of 2015.

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

Energy Efficiency Plan:  The Massachusetts EDCs and natural gas distribution companies have increased their energy efficiency savings achievements significantly since the enactment of the Green Communities Act in 2008, with electric savings almost tripling between 2008 and 2014.  On October 30, 2015, NSTAR Electric, WMECO, and NSTAR Gas filed for approval of the three-year electric and natural gas energy efficiency plan with the DPU, which was jointly developed with other Massachusetts EDCs and natural gas distribution companies.  As part of this plan, which covers the years 2016 through 2018, NSTAR Electric, WMECO, and NSTAR Gas are proposing to maintain aggressive savings goals.  The plan includes performance incentives related to these aggressive savings goals totaling $59 million over the three year period for NSTAR Electric, WMECO and NSTAR Gas, as well as recovery of LBR resulting from incremental efficiency savings of approximately $50 million on an annual basis for NSTAR Electric.

NSTAR Gas Distribution Rates:  On October 30, 2015, the DPU issued a final order in the NSTAR Gas distribution rate case, which approved an annualized base rate increase of $15.8 million effective January 1, 2016.  In the final order, the DPU also approved an authorized regulatory ROE of 9.8 percent, the establishment of a revenue decoupling reconciliation mechanism, and a 52.1 percent equity component of its capital structure.

New Hampshire:

PSNH Divestiture Agreement:  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 Staff of the NHPUC, the Office of Consumer Advocate, two State Senators, and several other parties.  The Agreement was filed with the NHPUC on the same day.  Under the terms of the Agreement, PSNH has agreed to divest its generation assets upon NHPUC approval.  The Agreement is designed to provide a resolution of issues pertaining to PSNH's generation assets in pending regulatory proceedings before the NHPUC.  When implemented, the Agreement provides for the Clean Air Project prudence proceeding to be resolved and all remaining Clean Air Project costs to be included in rates effective January 1, 2016.  As part of the Agreement, PSNH has agreed to forego recovery of $25 million of the deferred equity return related to the Clean Air Project.  In addition, PSNH will not seek a general distribution rate increase effective before July 1, 2017 and will contribute $5 million to create a clean energy fund, which will not be recoverable from its customers.  In the second quarter of 2015, PSNH recorded the $5 million contribution as a long-term liability and an increase to Operations and Maintenance expense on the statements of income.

Upon completion of the divestiture process, all remaining stranded costs, including any remaining deferred equity return in excess of the $25 million that PSNH has agreed to forego, will be recovered via bonds that will be secured by a non-bypassable charge in rates billed to PSNH's customers.  For further information on the securitization legislation that was signed into law on July 9, 2015, see "Legislative and Policy Matters – New Hampshire" in this Management's Discussion and Analysis of Financial Conditions and Results of Operations.

Implementation of the Agreement is subject to NHPUC approval, which is expected in early 2016.

Legislative and Policy Matters

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

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 2014 Form 10-K.  There have been no material changes with regard to these critical accounting policies.

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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 2014 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 Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to those reports may be reviewed.  Information contained on the Company's website or that can be accessed through the website is not incorporated into and does not constitute a part of this 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 nine months ended September 30, 2015 and 2014 included in this Quarterly Report on Form 10-Q:  

			For the Three Months Ended September 30,									For the Nine Months Ended September 30,
								Increase/								Increase/
(Millions of Dollars)			2015			2014		(Decrease)		Percent		2015		2014		(Decrease)		Percent
Operating Revenues			$	1,933.1		$	1,892.5	$	40.6	2.1	%	$	6,263.6	$	5,860.7	$	402.9	6.9	%
Operating Expenses:
	Purchased Power, Fuel and Transmission			702.6			716.6		(14.0)	(2.0)			2,549.8		2,319.0		230.8	10.0
	Operations and Maintenance			327.3			344.1		(16.8)	(4.9)			977.3		1,069.0		(91.7)	(8.6)
	Depreciation			167.9			153.2		14.7	9.6			495.4		456.2		39.2	8.6
	Amortization of Regulatory (Liabilities)/Assets, Net			(16.8)			(22.5)		5.7	25.3			42.6		31.8		10.8	34.0
	Energy Efficiency Programs			132.1			118.7		13.4	11.3			380.6		360.2		20.4	5.7
	Taxes Other Than Income Taxes			150.8			141.5		9.3	6.6			439.2		421.9		17.3	4.1
		Total Operating Expenses		1,463.9			1,451.6		12.3	0.8			4,884.9		4,658.1		226.8	4.9
Operating Income				469.2			440.9		28.3	6.4			1,378.7		1,202.6		176.1	14.6
Interest Expense				92.5			89.7		2.8	3.1			279.6		272.2		7.4	2.7
Other Income, Net				5.2			11.8		(6.6)	(55.9)			23.9		19.0		4.9	25.8
Income Before Income Tax Expense				381.9			363.0		18.9	5.2			1,123.0		949.4		173.6	18.3
Income Tax Expense				144.1			126.5		17.6	13.9			420.7		345.9		74.8	21.6
Net Income				237.8			236.5		1.3	0.5			702.3		603.5		98.8	16.4
Net Income Attributable to Noncontrolling Interests				1.9			1.9		-	-			5.6		5.6		-	-
Net Income Attributable to Common Shareholders			$	235.9		$	234.6	$	1.3	0.6	%	$	696.7	$	597.9	$	98.8	16.5	%
Operating Revenues
			For the Three Months Ended September 30,									For the Nine Months Ended September 30,
								Increase/									Increase/
(Millions of Dollars)			2015			2014		(Decrease)		Percent			2015		2014		(Decrease)	Percent
Electric Distribution			$		1,543.7	$	1,502.6	$	41.1	2.7	%	$	4,686.5	$	4,350.4	$	336.1	7.7	%
Natural Gas Distribution					106.2		109.2		(3.0)	(2.7)			799.6		737.5		62.1	8.4
	Total Distribution				1,649.9		1,611.8		38.1	2.4			5,486.1		5,087.9		398.2	7.8
Electric Transmission					270.4		262.5		7.9	3.0			787.2		721.4		65.8	9.1
	Total Regulated Companies				1,920.3		1,874.3		46.0	2.5			6,273.3		5,809.3		464.0	8.0
Other and Eliminations					12.8		18.2		(5.4)	(29.7)			(9.7)		51.4		(61.1)	(a)
Total Operating Revenues			$		1,933.1	$	1,892.5	$	40.6	2.1	%	$	6,263.6	$	5,860.7	$	402.9	6.9	%
(a)  Percent greater than 100 percent not shown as it is not meaningful.
A summary of our retail electric sales volumes and firm natural gas sales volumes were as follows:
			For the Three Months Ended September 30,									For the Nine Months Ended September 30,
								Increase/
			2015			2014		(Decrease)		Percent		2015		2014		Increase		Percent
Retail Electric Sales Volumes in GWh				15,206			14,555		651	4.5	%		42,174		41,439		735	1.8	%
Firm Natural Gas Sales Volumes in Million Cubic Feet				11,137			11,328		(191)	(1.7)			78,489		75,169		3,320	4.4

Three Months Ended:

Operating Revenues increased by $40.6 million for the three months ended September 30, 2015, as compared to the same period in 2014.  

Base electric distribution revenues:  Base electric distribution segment revenues increased $52.8 million due primarily to CL&P’s base distribution rate increase, approved by PURA on December 17, 2014, effective December 1, 2014 ($40.7 million).  In addition, CL&P recognized $4.6 million in Operating Revenues in the third quarter of 2015 due to a PURA-approved settlement agreement, which increased CL&P’s distribution revenue requirement through an adjustment to rate base associated with accumulated deferred income taxes (ADIT).  

Effective December 1, 2014, CL&P’s distribution revenues were decoupled from its sales volumes.  As a result, CL&P no longer earns LBR related to its energy efficiency programs.  This is similar to WMECO’s revenue decoupling mechanism in that it permits recovery of a base amount of distribution revenues ($1.059 billion annually for CL&P effective December 1, 2014) and effectively breaks the relationship between revenues and customer electricity usage.  Revenue decoupling mechanisms result in the recovery of our approved base distribution revenue requirements.  Therefore, changes in sales volumes have no impact on the level of base distribution revenue realized.

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 and natural gas supply costs, federally mandated congestion charges, retail electric transmission charges, energy efficiency program costs, system resiliency costs, certain uncollectible hardship bad debt expenses and restructuring and stranded costs as a result of deregulation.  Tracked electric distribution segment revenues decreased primarily as a result of a decrease in energy supply costs ($40.7 million) and a decrease in the federally mandated congestion charge primarily driven by refunds in 2015 for a prior year overrecovery ($25.7 million), partially offset by increases in stranded cost recoveries ($21.9 million), energy efficiency program cost revenues ($15.3 million) and retail transmission charges ($4.8 million).  Tracked natural gas distribution segment revenues decreased due primarily to a decrease in rates related to the recovery of costs associated with the procurement of natural gas supply ($13.2 million).

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Transmission revenues:  The electric transmission segment revenues increased by $7.9 million due primarily to recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Other:  Other revenues decreased due primarily to the sale of Eversource's unregulated contracting business, which was sold on April 13, 2015 ($14.3 million).

Nine Months Ended:

Operating Revenues increased by $402.9 million for the nine months ended September 30, 2015, as compared to the same period in 2014.  

Base electric and natural gas distribution revenues:  Base electric distribution segment revenues increased $124.5 million due primarily to CL&P’s base distribution rate increase, approved by PURA on December 17, 2014, effective December 1, 2014 ($107.3 million) and weather.  In addition, Operating Revenues increased $15.3 million at CL&P due to the PURA-approved settlement agreement regarding ADIT, $11 million for the 2014 Comprehensive Settlement Agreement associated with the recovery of LBR related to 2009 through 2011 energy efficiency programs at NSTAR Electric, and $18.5 million increase of LBR recognition at NSTAR Electric related to 2015 energy efficiency programs for the nine months ended September 30, 2015, as compared to the same period in 2014.  The $15.3 million represents the incremental revenue requirement recognized for the period December 1, 2014 through September 30, 2015, which will be collected from customers over a 24-month period commencing December 1, 2015.  The impact of colder winter weather experienced in the first quarter of 2015and the warmer weather in the third quarter of 2015 was the primary driver of the increase in retail electric sales volumes and base electric distribution revenues at NSTAR Electric and PSNH for the nine months ended September 30, 2015 compared to the same period in 2014.

Firm natural gas base distribution segment revenues increased $9.9 million as a result of the impact of colder winter weather experienced in the first quarter of 2015, resulting from a 4.4 percent increase in firm natural gas sales volumes for the nine months ended September 30, 2015, as compared to the same period in 2014.  The winter weather conditions experienced in the first quarter of 2015 were significantly colder than both normal and the same period last year throughout our natural gas service territories.  Weather-normalized firm natural gas sales volumes (based on 30-year average temperatures) increased 2.5 percent for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to residential and commercial customer growth and improved economic conditions.

Tracked distribution revenues: Tracked electric distribution segment revenues increased as a result of increases in energy supply costs ($297.4 million) and tracked natural gas distribution segment revenues increased due primarily to an increase in rates related to the recovery of costs associated with the procurement of natural gas supply ($25.8 million).  Energy and natural gas supply costs were impacted by the overall New England wholesale energy supply market in which natural gas delivery costs adversely impacted the cost of electric energy purchased for our retail electric customers and the cost of natural gas purchased on behalf of our retail natural gas customers.  These increases were partially offset by a decrease in retail electric transmission charges ($80.3 million) and a decrease in the federally mandated congestion charge primarily driven by refunds in 2015 for a prior year overrecovery ($82.4 million).

Electric transmission revenues:  The electric transmission segment revenues increased by $65.8 million due primarily to the impact of a lower FERC ROE complaint proceedings reserve recorded in 2015 as compared to 2014 and the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure.

Other:  Other revenues decreased due primarily to the sale of Eversource's unregulated contracting business on April 13, 2015 ($42.5 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 decreased for the three months ended September 30, 2015 and increased for the nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to the following:

	Three Months Ended		Nine Months Ended
(Millions of Dollars)	Increase/(Decrease)		Increase/(Decrease)
Electric Distribution	$	(19.2)	$	197.3
Natural Gas Distribution		(4.6)		48.9
Transmission		0.6		2.3
Other and Eliminations		9.2		(17.7)
Total Purchased Power, Fuel and Transmission	$	(14.0)	$	230.8

The decrease in purchased power costs for the three months ended September 30, 2015 at the electric distribution business was driven by lower prices associated with the procurement of energy supply, as compared to the same period in 2014.  The decrease in purchased power costs at the natural gas distribution business was due to lower average natural gas prices for the three months ended September 30, 2015, as compared to the same period in 2014.

The increases in purchased power costs for the nine months ended September 30, 2015 at the electric and natural gas distribution businesses were driven by the higher prices associated with the procurement of energy supply in the first half of 2015, as compared to the same period in 2014.  Our energy supply prices were impacted by higher natural gas delivery costs which, in addition to its impact on the price of natural gas purchased on behalf of our retail natural gas customers, had an adverse impact on the price of electric energy purchased for our retail electric customers.  

Operations and Maintenance expense includes tracked costs and costs that are part of base electric and natural gas distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance decreased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to the following:

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	Three Months Ended		Nine Months Ended
(Millions of Dollars)	Increase/(Decrease)		Increase/(Decrease)
Base Electric Distribution:
Resolution of basic service bad debt adder mechanism at NSTAR Electric	$	-	$	(24.2)
Decrease in employee-related expenses, including labor and benefits		(5.1)		(15.7)
Contribution to create clean energy fund in connection with the generation     divestiture agreement at PSNH		-		5.0
Bad debt expense		4.8		4.6
Storm restoration costs		1.1		4.5
Lower contractor costs due to timing of capital projects at CL&P		(4.4)		(1.4)
Other operations and maintenance		(0.8)		(0.5)
Total Base Electric Distribution		(4.4)		(27.7)
Total Base Natural Gas Distribution		(1.6)		(5.2)
Total Tracked costs (Transmission and Electric and Natural Gas Distribution)		3.4		(4.7)
Total Distribution and Transmission		(2.6)		(37.6)
Other and eliminations:
Reorganizational costs		(1.6)		(7.8)
Absence of Eversource's unregulated electrical contracting business due to sale     in April 2015, net		(9.4)		(34.8)
ES Parent and Other Companies		(3.2)		(11.5)
Total Operations and Maintenance	$	(16.8)	$	(91.7)

Depreciation increased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to higher utility plant in service balances resulting from completed construction projects placed into service and an increase in depreciation rates at CL&P as a result of the distribution rate case effective December 1, 2014.  

Amortization of Regulatory (Liabilities)/Assets, Net, which are tracked costs, include certain regulatory-approved tracking mechanisms.  Fluctuations in these costs are recovered from customers in rates and have no impact on earnings.  Amortization of Regulatory (Liabilities)/Assets, Net, increased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to the following:

	Three Months Ended		Nine Months Ended
(Millions of Dollars)	Increase/(Decrease)		Increase/(Decrease)
CL&P:
Amortization increase (including storm cost recovery) approved and included in     base distribution rates	$	16.5	$	49.6
Energy and energy-related supply costs tracking mechanism		(52.5)		(94.3)
NSTAR Electric (primarily transition costs tracking mechanism, and for the nine     months ended the recognition of the 2014 Comprehensive Settlement Agreement)		17.3		(9.7)
PSNH (primarily default energy service charge tracking mechanism)		11.7		46.8
WMECO		12.4		19.0
Other		0.3		(0.6)
Total Amortization of Regulatory Assets, Net	$	5.7	$	10.8

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

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

Energy Efficiency Programs, which are tracked costs, increased for the three and nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to an increase in energy efficiency costs in accordance with the three-year program guidelines established by the DPU at NSTAR Electric.  

Taxes Other Than Income Taxes increased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to an increase in property taxes as a result of both an increase in utility plant balances and property tax rates.

Interest Expense increased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to higher interest on long-term debt ($2.4 million and $4.1 million, respectively), and higher interest on short-term borrowings, partially offset by lower interest on regulatory deferral mechanisms for the three months ended September 30, 2015.

Other Income, Net decreased for the three months ended September 30, 2015, as compared to the same period in 2014, due primarily to the absence in 2015 of a gain on the sale of land recorded in the third quarter of 2014 ($4.5 million) and a decrease in net gains related to the deferred compensation plans ($2 million).

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Other Income, Net increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to higher AFUDC related to equity funds ($3.6 million) and an increase in net gains related to the deferred compensation plans ($1.8 million).

Income Tax Expense increased for the three months ended September 30, 2015, as compared to the same period in 2014, due primarily to higher pre-tax earnings ($6.4 million), the impact of reconciling our provision for income taxes to what was filed on our tax return (return to provision) and a lower tax benefit in 2015 compared to 2014 from a reduction in tax reserves ($11.8 million).

Income Tax Expense increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to higher pre-tax earnings ($59.6 million), higher state income taxes ($4.4 million), the impact of the return to provision and a lower tax benefit in 2015 compared to 2014 from a reduction in tax reserves ($13.2 million), partially offset by items that impact our tax rate as a result of regulatory treatment (flow-through items) ($2.9 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 nine months ended September 30, 2015 and 2014 included in this Quarterly Report on Form 10-Q:  

			For the Three Months Ended September 30,								For the Nine Months Ended September 30,
							Increase/								Increase/
(Millions of Dollars)			2015		2014		(Decrease)		Percent		2015		2014		(Decrease)		Percent
Operating Revenues			$	704.3	$	695.6	$	8.7	1.3	%	$	2,175.7	$	2,017.6	$	158.1	7.8	%
Operating Expenses:
	Purchased Power and Transmission			274.8		255.8		19.0	7.4			861.6		737.0		124.6	16.9
	Operations and Maintenance			122.3		127.2		(4.9)	(3.9)			358.3		368.6		(10.3)	(2.8)
	Depreciation			54.8		46.9		7.9	16.8			159.9		139.6		20.3	14.5
	Amortization of Regulatory (Liabilities)/Assets, Net			(22.9)		13.1		(36.0)	(a)			17.9		62.6		(44.7)	(71.4)
	Energy Efficiency Programs			42.6		41.4		1.2	2.9			119.4		119.4		-	-
	Taxes Other Than Income Taxes			71.6		65.0		6.6	10.2			201.7		194.1		7.6	3.9
		Total Operating Expenses		543.2		549.4		(6.2)	(1.1)			1,718.8		1,621.3		97.5	6.0
Operating Income				161.1		146.2		14.9	10.2			456.9		396.3		60.6	15.3
Interest Expense				36.7		38.7		(2.0)	(5.2)			109.5		110.4		(0.9)	(0.8)
Other Income, Net				2.4		6.4		(4.0)	(62.5)			8.6		10.6		(2.0)	(18.9)
Income Before Income Tax Expense				126.8		113.9		12.9	11.3			356.0		296.5		59.5	20.1
Income Tax Expense				46.6		30.0		16.6	55.3			127.8		95.9		31.9	33.3
Net Income			$	80.2	$	83.9	$	(3.7)	(4.4)	%	$	228.2	$	200.6	$	27.6	13.8	%
(a) Percent greater than 100 percent not shown as it is not meaningful.
Operating Revenues
CL&P's retail sales volumes were as follows:
			For the Three Months Ended September 30,								For the Nine Months Ended September 30,
			2015		2014		Increase		Percent		2015		2014		Increase		Percent
Retail Sales Volumes in GWh				6,103		5,791		312	5.4	%		17,123		16,790		333	2.0	%

Three Months Ended:

CL&P's Operating Revenues increased by $8.7 million for the three months ended September 30, 2015, as compared to the same period in 2014.  

Base distribution revenues:  Base distribution revenues increased $40.7 million due to a base distribution rate increase approved by PURA on December 17, 2014, effective December 1, 2014.  In addition, CL&P recognized $4.6 million in Operating Revenues in the third quarter of 2015 due to a PURA-approved settlement agreement, which increased CL&P’s distribution revenue requirement through an adjustment to rate base associated with ADIT.  

Effective December 1, 2014, CL&P’s distribution revenues were decoupled from its sales volumes.  As a result, CL&P no longer earns LBR related to its energy efficiency programs.  The revenue decoupling mechanism permits recovery of a base amount of distribution revenues ($1.059 billion annually effective December 1, 2014) and effectively breaks the relationship between revenues and customer electricity usage.  Revenue decoupling mechanisms result in the recovery of our approved base distribution revenue requirements.  Therefore, changes in sales volumes have no impact on the level of base distribution revenue realized.

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 costs, retail transmission charges, energy efficiency program costs, system resiliency costs and uncollectible hardship bad debt expense.  Tracked distribution revenues decreased primarily as a result of a decrease in energy supply costs ($38.2 million) and a decrease in the federally mandated congestion charge primarily driven by refunds in 2015 for a prior year overrecovery ($25.7 million), partially offset by an increase in retail transmission charges ($30.7 million).

Nine Months Ended:

CL&P's Operating Revenues increased by $158.1 million for the nine months ended September 30, 2015, as compared to the same period in 2014.  

Base distribution revenues:  Base distribution revenues increased $107.3 million due to a base distribution rate increase approved by PURA on December 17, 2014, effective December 1, 2014.  In addition, CL&P recognized $15.3 million in Operating Revenues due to the PURA-approved settlement agreement regarding ADIT.  The $15.3 million represents the incremental revenue requirement for the period December 1, 2014 through September 30, 2015, which will be collected from customers over a 24-month period commencing December 1, 2015.

Tracked revenues:  Tracked distribution revenues increased primarily as a result of an increase in energy supply costs ($110.9 million), partially offset by a decrease in the federally mandated congestion charge primarily driven by refunds in 2015 for a prior year overrecovery ($82.4 million) and a decrease in competitive transition assessment charges ($13.1 million).  

Transmission revenues increased by $18.7 million due primarily to the impact of a lower FERC ROE complaint proceedings reserve recorded in 2015 as compared to 2014 and the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure.

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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 increased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to the following:

	Three Months Ended		Nine Months Ended
(Millions of Dollars)	Increase/(Decrease)		Increase/(Decrease)
Purchased Power Costs	$	(9.8)	$	126.4
Transmission Costs		28.7		(0.8)
Other		0.1		(1.0)
Total Purchased Power and Transmission	$	19.0	$	124.6

Included in purchased power are the costs associated with CL&P's generation services charge (GSC) and deferred energy costs.  The GSC recovers energy-related costs incurred as a result of providing electric generation service supply to all customers that have not migrated to competitive energy suppliers.  The decrease in purchased power costs for the three months ended September 30, 2015 was due primarily to a decrease in the GSC cost deferral.  The increase in purchased power costs for the nine months ended September 30, 2015 was due primarily to higher prices associated with the procurement of energy supply related to standard offer from third party suppliers.  The increase in transmission costs for the three months ended September 30, 2015 was primarily the result of an increase in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.  

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance decreased for the three months ended September 30, 2015, as compared to the same period in 2014, driven by a $6.7 million decrease in non-tracked costs, which was primarily attributable to lower employee-related expenses and lower contractor costs due to timing of capital projects, partially offset by higher bad debt expense.  Tracked costs, which have no earnings impact, increased $1.8 million, which was primarily attributable to higher tracked bad debt expense.

Operations and Maintenance decreased for the nine months ended September 30, 2015, as compared to the same period in 2014, driven by a $14.7 million decrease in non-tracked costs, which was primarily attributable to lower employee-related expenses, partially offset by higher bad debt expense and higher storm restoration costs.  Tracked costs, which have no earnings impact, increased $4.4 million, which was primarily attributable to higher tracked bad debt expense.

Depreciation increased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to an increase in depreciation rates as a result of the distribution rate case decision that was effective December 1, 2014 and higher utility plant in service balances.  

Amortization of Regulatory (Liabilities)/Assets, Net¸ decreased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to a decrease in the deferral of energy supply and energy-related costs that can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs ($52.5 million and $94.3 million decreases for the three and nine month periods in 2015 as compared to 2014, respectively), partially offset by an increase in storm cost recovery and other cost recovery approved and included in distribution rates effective December 1, 2014 ($16.5 million and $49.6 million increases for the three and nine month periods in 2015 as compared to 2014, respectively).  Fluctuations in energy supply and energy-related costs, which are the primary drivers in amortization, are recovered from customers in rates and have no impact on earnings.  

Taxes Other Than Income Taxes increased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to an increase in property taxes as a result of both an increase in utility plant balances and property tax rates.

Interest Expense decreased for the three months ended September 30, 2015, as compared to the same period in 2014, due primarily to lower interest on regulatory deferral mechanisms.

Other Income, Net decreased for the three and nine months ended September 30, 2015, as compared to the same periods in 2014, due primarily to the absence in 2015 of a gain on the sale of land recorded in the third quarter of 2014 ($4.5 million), partially offset by higher AFUDC related to equity funds ($0.2 million and $1.6 million, respectively).

Income Tax Expense increased for the three months ended September 30, 2015, as compared to the same period in 2014, due primarily to higher pre-tax earnings ($4.5 million), the impact of the return to provision and a lower tax benefit in 2015 compared to 2014 from a reduction in tax reserves ($13.2 million), partially offset by the flow-through items ($1.2 million).

Income Tax Expense increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to higher pre-tax earnings ($20.8 million), higher state income taxes ($1.8 million), the impact of the return to provision and a lower tax benefit in 2015 compared to 2014 from a reduction in tax reserves ($12.5 million), partially offset by the flow-through items ($3.4 million).

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EARNINGS SUMMARY

CL&P's earnings decreased $3.7 million for the three months ended September 30, 2015, as compared to the same period in 2014, driven by higher income tax expense due to the absence of favorable state income tax benefits recorded in the third quarter of 2014, the absence of a gain on the sale of land recorded in the third quarter of 2014, higher property taxes and higher depreciation expense.  These unfavorable earnings impacts were partially offset by higher distribution revenues due primarily to the impact of the December 1, 2014 base distribution rate increase, the PURA-approved settlement agreement, which increased CL&P’s distribution revenues through an adjustment to rate base associated with ADIT, and lower operations and maintenance costs, which were primarily attributable to lower employee-related expenses.  

CL&P's earnings increased $27.6 million for the nine months ended September 30, 2015, as compared to the same period in 2014, driven by higher distribution revenues due primarily to the impact of the December 1, 2014 base distribution rate increase and the PURA-approved settlement agreement, which increased CL&P’s distribution revenues.  In addition, earnings increased due to lower operations and maintenance costs, which were primarily attributable to lower employee-related expenses, and the impact of the lower FERC ROE complaint proceedings reserve recorded in 2015, as compared to 2014.  These favorable earnings impacts were partially offset by higher income tax expense due to the absence of favorable state income tax benefits recorded in 2014, the absence of a gain on the sale of land recorded in 2014, higher property taxes and higher depreciation expense.

LIQUIDITY

CL&P had cash flows provided by operating activities of $421.8 million for the nine months ended September 30, 2015, as compared to $483 million in the same period of 2014.  The decrease in operating cash flows was due primarily to the absence of the receipt of $68.6 million in DOE Phase II Damages proceeds received on June 1, 2014 from the Yankee Companies, the timing of regulatory recoveries resulting from the increase in federally mandated congestion charges, and the timing of collections and payments related to our working capital items, including accounts receivable and accounts payable.  Accounts receivable increased due to an increase in standard offer rates effective January 1, 2015 and an increase in base distribution rates effective December 1, 2014.  Partially offsetting these unfavorable impacts were net income tax refunds of $3.8 million in 2015, compared with income tax payments of $85.3 million in 2014.

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.  For the nine months ended September 30, 2015, investments for CL&P were $359.3 million.

On October 26, 2015, Eversource parent and certain of its subsidiaries, including CL&P, amended and restated their joint five-year $1.45 billion revolving credit facility and extended the termination date to September 4, 2020.  The facility serves to backstop Eversource parent's $1.45 billion commercial paper program.  The commercial paper program allows Eversource parent to issue commercial paper as a form of short-term debt with intercompany loans to certain subsidiaries, including CL&P.  As of December 31, 2014, there were intercompany loans from Eversource parent of $133.4 million to CL&P.

Financing activities for the nine months ended September 30, 2015 included $147 million in common stock dividends paid to Eversource parent.

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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 nine months ended September 30, 2015 and 2014 included in this Quarterly Report on Form 10-Q:  

			For the Nine Months Ended September 30,
(Millions of Dollars)							Increase/
			2015		2014		(Decrease)		Percent
Operating Revenues			$	2,134.7	$	1,955.6	$	179.1	9.2	%
Operating Expenses:
	Purchased Power and Transmission			984.0		879.8		104.2	11.8
	Operations and Maintenance			228.8		244.6		(15.8)	(6.5)
	Depreciation			146.8		141.0		5.8	4.1
	Amortization of Regulatory Liabilities, Net			(10.6)		(0.9)		(9.7)	(a)
	Energy Efficiency Programs			164.8		145.5		19.3	13.3
	Taxes Other Than Income Taxes			95.8		99.1		(3.3)	(3.3)
		Total Operating Expenses		1,609.6		1,509.1		100.5	6.7
Operating Income				525.1		446.5		78.6	17.6
Interest Expense				57.2		59.1		(1.9)	(3.2)
Other Income, Net				3.6		3.0		0.6	20.0
Income Before Income Tax Expense				471.5		390.4		81.1	20.8
Income Tax Expense				187.4		156.6		30.8	19.7
Net Income			$	284.1	$	233.8	$	50.3	21.5	%
(a) Percent greater than 100 percent not shown as it is not meaningful.
Operating Revenues
NSTAR Electric's retail sales volumes were as follows:
			For the Nine Months Ended September 30,
			2015		2014		Increase		Percent
Retail Sales Volumes in GWh				16,260		15,958		302	1.9	%

NSTAR Electric's Operating Revenues increased by $179.1 million for the nine months ended September 30, 2015, as compared to the same period in 2014.  

Base distribution revenues:  Base distribution revenues increased $10.2 million as a result of the impact of colder winter weather experienced in the first quarter of 2015and the warmer weather in the third quarter of 2015, partially offset by the impact of our customer energy efficiency programs, resulting in a 1.9 percent increase in sales volumes for the nine months ended September 30, 2015, as compared to the same period in 2014.  The reduction to sales volumes associated with our energy efficiency programs was offset by the recognition of an $18.5 million increase in LBR for the nine months ended September 30, 2015, as compared to the same period in 2014.  

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 and transition cost recovery revenues.  Tracked distribution revenues increased primarily as a result of increases in energy supply costs ($151 million) and increased cost recovery related to our energy efficiency programs ($20.1 million).  Energy supply costs are impacted by the overall New England wholesale energy supply market in which natural gas delivery costs adversely impacted the cost of energy purchased for our retail customers.  These increases were partially offset by decreased retail transmission charges ($69 million).

Transmission revenues increased by $27 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure and the impact of a lower FERC ROE complaint proceedings reserve recorded in 2015 as compared to 2014.

Other:  In connection with the 2014 Comprehensive Settlement Agreement, NSTAR Electric recognized an $11 million benefit associated with the recovery of LBR related to 2009 through 2011 energy efficiency programs in the first quarter of 2015, which was recorded as an increase to Operating Revenues.  For further information, see "Regulatory Developments and Rate Matters – Massachusetts – NSTAR Electric and NSTAR Gas 2014 Comprehensive Settlement Agreement" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

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 increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to the following:  

(Millions of Dollars)	Increase/(Decrease)
Purchased Power Costs	$	157.6
Transmission Costs		(53.4)
Total Purchased Power and Transmission	$	104.2

Included in purchased power 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 that have not migrated to competitive energy suppliers.  The increase in purchased power costs was due primarily to higher prices associated with the procurement

49

of energy supply.  The decrease in transmission costs was primarily the result of a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.

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 decreased for the nine months ended September 30, 2015, as compared to the same period in 2014, driven by a $7.5 million reduction in non-tracked costs, which was primarily attributable to the resolution of the basic service bad debt adder mechanism ($24.2 million), partially offset by an increase in employee-related costs expensed and not capitalized, as a result of the impact from winter weather and storms in 2015 compared to 2014.  Tracked costs, which have no earnings impact, decreased $8.3 million, which was primarily attributable to lower employee-related expenses.

Depreciation increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to higher utility plant in service balances.  

Amortization of Regulatory Liabilities, Net, reflects an $11.7 million benefit recognized in connection with the 2014 Comprehensive Settlement Agreement at NSTAR Electric associated with the settlement with the Massachusetts Attorney General on eleven open dockets covering the CPSL program filings in the first quarter of 2015, which was recorded as a reduction to amortization expense.  For further information, see "Regulatory Developments and Rate Matters – Massachusetts – NSTAR Electric and NSTAR Gas 2014 Comprehensive Settlement Agreement" in this Management's Discussion and Analysis of Financial Condition and Results of Operations.  Partially offsetting this benefit was an increase in the recovery of previously deferred tracked transition costs for the nine months ended September 30, 2015, as compared to the same period in 2014.  Fluctuations in these costs are recovered from customers in rates and have no impact on earnings.  

Energy Efficiency Programs, which are tracked costs, increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to an increase in energy efficiency costs incurred in accordance with the three-year program guidelines established by the DPU.  

Income Tax Expense increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to higher pre-tax earnings ($28.4 million) and higher state income taxes ($4.6 million).

EARNINGS SUMMARY

NSTAR Electric's earnings increased $50.3 million for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to the resolution of the basic service bad debt adder mechanism ($14.5 million), the favorable impact associated with the 2014 Comprehensive Settlement Agreement related to the settlement with the Massachusetts Attorney General on eleven open dockets covering the CPSL program filings and the recovery of LBR related to 2009 through 2011 energy efficiency programs ($13 million), the recovery of higher LBR related to 2015 energy efficiency programs, higher retail sales volumes, and the impact of the lower FERC ROE complaint proceedings reserve recorded in 2015, as compared to 2014.  These favorable earnings impacts were partially offset by an increase in operations and maintenance costs due primarily to an increase in employee-related costs expensed and not capitalized, as a result of the impact from winter weather and storms in 2015, as compared to 2014, and higher depreciation expense.   

LIQUIDITY

NSTAR Electric had cash flows provided by operating activities of $502.3 million for the nine months ended September 30, 2015, as compared to $517.5 million in the same period of 2014.  The decrease in operating cash flows was due primarily to the timing of regulatory recoveries resulting from the increase in purchased power costs and the timing of collections and payments related to our working capital items, including affiliated company receivables, accounts receivable and accounts payable.  Accounts receivable increased due primarily to an increase in basic service rates effective January 1, 2015.  Also contributing to the decrease in operating cash flows was the absence of the receipt of $30.2 million in DOE Phase II Damages proceeds received on June 1, 2014 from the Yankee Companies.  Partially offsetting these unfavorable impacts were income tax refunds of $71.5 million for the nine months ended September 30, 2015 compared to income tax payments of $134.8 million for the nine months ended September 30, 2014, and the favorable impact in the timing of materials and supplies purchases.  

On October 26, 2015, NSTAR Electric amended and restated its five-year $450 million revolving credit facility and extended the termination date to September 4, 2020.  The facility serves to backstop NSTAR Electric's $450 million commercial paper program.  As of September 30, 2015 and December 31, 2014, NSTAR Electric had $258.5 million and $302 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $191.5 million and $148 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively.  The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.18 percent and 0.27 percent, respectively.  

50

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

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for PSNH for the nine months ended September 30, 2015 and 2014 included in this Quarterly Report on Form 10-Q:  

			For the Nine Months Ended September 30,
							Increase/
(Millions of Dollars)			2015		2014		(Decrease)		Percent
Operating Revenues			$	761.1	$	735.1	$	26.0	3.5	%
Operating Expenses:
	Purchased Power, Fuel and Transmission			200.5		248.0		(47.5)	(19.2)
	Operations and Maintenance			200.1		198.0		2.1	1.1
	Depreciation			78.0		73.2		4.8	6.6
	Amortization of Regulatory Assets/(Liabilities), Net			29.2		(17.6)		46.8	(a)
	Energy Efficiency Programs			11.0		10.9		0.1	0.9
	Taxes Other Than Income Taxes			61.4		53.1		8.3	15.6
		Total Operating Expenses		580.2		565.6		14.6	2.6
Operating Income				180.9		169.5		11.4	6.7
Interest Expense				34.6		34.0		0.6	1.8
Other Income, Net				2.3		1.7		0.6	35.3
Income Before Income Tax Expense				148.6		137.2		11.4	8.3
Income Tax Expense				56.1		52.2		3.9	7.5
Net Income			$	92.5	$	85.0	$	7.5	8.8	%
(a) Percent greater than 100 percent not shown as it is not meaningful.
Operating Revenues
PSNH's retail sales volumes were as follows:
			For the Nine Months Ended September 30,
			2015		2014		Increase		Percent
Retail Sales Volumes in GWh				6,049		5,970		79	1.3	%

PSNH's Operating Revenues increased by $26 million for the nine months ended September 30, 2015, as compared to the same period in 2014.

Base distribution revenues:  Base distribution revenues increased $7 million as a result of a 1.3 percent increase in sales volumes for the nine months ended September 30, 2015, as compared to the same period in 2014, primarily related to the impact of colder winter weather experienced in the first quarter of 2015, the warmer weather in the third quarter of 2015and 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 increased primarily as a result of increases in energy supply costs partially offset by a reduction in wholesale generation revenues ($6.1 million) for the nine months ended September 30, 2015, as compared to the same period in 2014.

Transmission revenues increased by $10.6 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure and the impact of a lower FERC ROE complaint proceedings reserve recorded in 2015 as compared to 2014.

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 decreased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to the following:

(Millions of Dollars)	Decrease
Generation Fuel Costs	$	(16.7)
Purchased Power Costs		(17.4)
Transmission Costs		(11.4)
Other		(2.0)
Total Purchased Power, Fuel and Transmission	$	(47.5)

PSNH procures power through its own generation, long-term power supply contracts and short-term purchases and spot purchases in the competitive New England wholesale power market.  The decrease in generation fuel costs was due primarily to a decrease in the amount of electricity generated by PSNH facilities for the nine months ended September 30, 2015, as compared to the same period in 2014.  The decrease in purchased power costs was due to lower power prices of short-term and spot purchases made in the wholesale power market for the nine months ended September 30, 2015, as compared to the same period in 2014.  The decrease in transmission costs for the nine months ended September 30, 2015 was primarily the result of a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.

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 increased for the nine months ended September 30, 2015, as compared to the same period in 2014, driven by a $2 million increase in tracked costs, which have no earnings impact, that was primarily attributable to higher tracked bad debt expense,

51

and a $0.1 million increase in non-tracked costs, which was primarily attributable to a $5 million contribution to create a clean energy fund that was recorded in the second quarter of 2015 in connection with the generation divestiture agreement, which is not recoverable from customers, offset by lower employee-related expenses.

Depreciation increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to higher utility plant in service balances.  

Amortization of Regulatory Assets/(Liabilities), Net, reflects an increase in the deferral to expense of energy supply costs and other amortizations for the nine months ended September 30, 2015, as compared to the same period in 2014.  Fluctuations in these costs are recovered from customers in rates and have no impact on earnings.  

Taxes Other Than Income Taxes increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to an increase in property taxes as a result of an increase in utility plant balances.

Income Tax Expense increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due to higher pre-tax earnings ($4 million).

EARNINGS SUMMARY

PSNH's earnings increased $7.5 million for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to the impact of the distribution rate increase effective July 1, 2015, higher retail sales volumes, a decrease in operations and maintenance costs due primarily to lower employee-related expense, and the lower FERC ROE complaint proceedings reserve recorded in 2015, as compared to 2014.  Partially offsetting these favorable earnings impacts were a $5 million contribution to create a clean energy fund that was recorded in the second quarter of 2015 in connection with the generation divestiture agreement, which is not recoverable from customers, higher depreciation expense and higher property tax expense.  

LIQUIDITY

PSNH had cash flows provided by operating activities of $243.9 million for the nine months ended September 30, 2015, as compared to $205.8 million in the same period in 2014.  The increase in operating cash flows was due primarily to the timing of fuel, materials and supplies and a decrease in net income tax payments in 2015 compared with the same period in 2014.  Partially offsetting these favorable impacts were the timing of collections and payments related to our working capital items, including accounts receivable and accounts payable, and the absence of the receipt of $14.5 million in DOE Phase II Damages proceeds received on June 1, 2014 from the Yankee Companies.    

52

RESULTS OF OPERATIONS – WESTERN MASSACHUSETTS ELECTRIC COMPANY

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for WMECO for the nine months ended September 30, 2015 and 2014 included in this Quarterly Report on Form 10-Q:  

			For the Nine Months Ended September 30,
							Increase/
(Millions of Dollars)			2015		2014		(Decrease)		Percent
Operating Revenues			$	403.2	$	363.8	$	39.4	10.8	%
Operating Expenses:
	Purchased Power and Transmission			149.2		131.0		18.2	13.9
	Operations and Maintenance			61.7		67.1		(5.4)	(8.0)
	Depreciation			32.4		31.1		1.3	4.2
	Amortization of Regulatory Assets/(Liabilities), Net			11.2		(7.8)		19.0	(a)
	Energy Efficiency Programs			32.7		33.1		(0.4)	(1.2)
	Taxes Other Than Income Taxes			28.4		25.7		2.7	10.5
		Total Operating Expenses		315.6		280.2		35.4	12.6
Operating Income				87.6		83.6		4.0	4.8
Interest Expense				19.0		18.9		0.1	0.5
Other Income, Net				2.4		1.7		0.7	41.2
Income Before Income Tax Expense				71.0		66.4		4.6	6.9
Income Tax Expense				28.6		26.6		2.0	7.5
Net Income			$	42.4	$	39.8	$	2.6	6.5	%
(a)  Percent greater than 100 percent not shown as it is not meaningful.
Operating Revenues
WMECO's retail sales volumes were as follows:
			For the Nine Months Ended September 30,
			2015		2014		Increase		Percent
Retail Sales Volumes in GWh				2,742		2,721		21	0.8	%

Fluctuations in WMECO's sales volumes have no impact on total operating revenues or earnings, as WMECO’s revenues are decoupled from sales volumes.  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, transmission related costs, energy efficiency programs, and restructuring and stranded costs as a result of deregulation.

WMECO's Operating Revenues increased by $39.4 million for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to an increase in energy supply costs ($29.4 million).  Energy supply costs are impacted by the overall New England wholesale energy supply market in which higher natural gas delivery costs adversely impacted the cost of energy purchased for our retail customers.  The increase was partially offset by a $3.9 million decrease in revenues that impacts earnings due to the absence of a 2014 wholesale billing adjustment.  

Transmission revenues increased by $9.4 million due primarily to the recovery of higher revenue requirements associated with ongoing investments in our transmission infrastructure and the impact of a lower FERC ROE complaint proceedings reserve recorded in 2015 as compared to 2014.

Purchased Power and Transmission expense includes costs associated with the procurement 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 increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to the following:

(Millions of Dollars)	Increase/(Decrease)
Purchased Power Costs	$	27.5
Transmission Costs		(9.3)
Total Purchased Power and Transmission	$	18.2

Included in purchased power 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 that have not migrated to competitive energy suppliers.  The increase in purchased power costs was due primarily to higher prices associated with the procurement of energy supply.  The decrease in transmission costs was as a result of a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.  

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 decreased for the nine months ended September 30, 2015, as compared to the same period in 2014, driven by a $4 million reduction in non-tracked costs, which was primarily attributable to lower employee-related expenses and a decrease in workers' compensation claims, partially offset by higher bad debt expense, and a $1.4 million reduction in tracked costs, which have no earnings impact, that was primarily attributable to lower employee-related expenses, partially offset by higher tracked bad debt expense.

Amortization of Regulatory Assets/(Liabilities), Net, reflects the absence of the refund of the DOE proceeds to customers in 2014 as well as other energy and energy related costs and amortizations that can fluctuate period to period based on timing of costs incurred and related rate changes to recover these costs.  Fluctuations in energy and energy related costs are recovered from customers in rates and have no impact on earnings.  

Taxes Other Than Income Taxes increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to an increase in property taxes as a result of an increase in utility plant balances and property tax rates.

Income Tax Expense increased for the nine months ended September 30, 2015, as compared to the same period in 2014, due to higher pre-tax earnings ($1.6 million).

EARNINGS SUMMARY

WMECO's earnings increased $2.6 million for the nine months ended September 30, 2015, as compared to the same period in 2014, due primarily to the impact of the lower FERC ROE complaint proceedings reserve recorded in 2015, as compared to 2014, and a decrease in operations and maintenance costs primarily attributable to lower employee-related expenses and a decrease in workers' compensation claims.  Partially offsetting these favorable earnings impacts was the absence of a 2014 wholesale billing adjustment, which favorably impacted 2014 revenues and interest expense.

LIQUIDITY

WMECO had cash flows provided by operating activities of $68 million for the nine months ended September 30, 2015, as compared to $120.6 million in the same period in 2014.  The decrease in operating cash flows was due primarily to the timing of collections and payments related to our working capital items, including accounts receivable.  Accounts receivable increased due primarily to an increase in basic service rates effective January 1, 2015.  In addition, the decrease in operating cash flows was due to the timing of regulatory recoveries resulting from the increase in purchased power costs, and the absence of the receipt of $18.9 million in DOE Phase II Damages proceeds received on June 1, 2014 from the Yankee Companies.  Partially offsetting these unfavorable cash flow impacts were net income tax refunds of $0.6 million in 2015 compared with net income tax payments of $26.5 million in 2014.

53

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 September 30, 2015, our Regulated companies did not hold  collateral (letters of credit) from counterparties related to our standard service contracts.  As of September 30, 2015, Eversource had cash posted of approximately $15.1 million 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 2014 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 2014 Form 10-K.

ITEM 4.

CONTROLS AND PROCEDURES

Management, on behalf of Eversource, CL&P, NSTAR Electric, PSNH and WMECO, evaluated the design and operation of the disclosure controls and procedures as of September 30, 2015 to determine whether they are effective in ensuring that the disclosure of required information is made timely and in accordance with the Securities Exchange Act of 1934 and the rules and regulations of the SEC.  This evaluation was made under management's supervision and with management's participation, including the principal executive officer and principal financial officer as of the end of the period covered by this 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 September 30, 2015 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.

54

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 2014 Form 10-K.  These disclosures are incorporated herein by reference.  There have been no additional material legal proceedings identified and no material changes with regard to the legal proceedings previously disclosed in our 2014 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 2014 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 2014 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)
July 1 – July 31, 2015	121,847	$	45.92	-	-
August 1 – August 31, 2015	176,419		51.76	-	-
September 1  – September 30, 2015	1,755		46.83	-	-
Total	300,021	$	49.36	-	-

55

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)

10.1

Twelfth Supplemental Indenture of Mortgage and Deed of Trust, dated as of September 1, 2015, between Yankee Gas Services Company and The Bank of New York Mellon Trust Company, N.A., successor as Trustee to The Bank of New York, as successor to Fleet National Bank (formerly known as The Connecticut National Bank)

12

Ratio of Earnings to Fixed Charges

31

Certification of Thomas J. May, Chairman, President and Chief Executive Officer of Eversource Energy, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of Eversource Energy, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

32

Certification of Thomas J. May, Chairman, President and Chief Executive Officer of Eversource Energy, and James J. Judge, Executive Vice President and Chief Financial Officer of Eversource Energy, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

Listing of Exhibits (CL&P)

12

Ratio of Earnings to Fixed Charges

31

Certification of Thomas J. May, Chairman of The Connecticut Light and Power Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of The Connecticut Light and Power Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

32

Certification of Thomas J. May, Chairman of The Connecticut Light and Power Company, and James J. Judge, Executive Vice President and 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, dated November 6, 2015

Listing of Exhibits (NSTAR Electric Company)

12

Ratio of Earnings to Fixed Charges

31

Certification of Thomas J. May, Chairman of NSTAR Electric Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of NSTAR Electric Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

32

Certification of Thomas J. May, Chairman of NSTAR Electric Company, and James J. Judge, Executive Vice President and 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, dated November 6, 2015

56

Listing of Exhibits (PSNH)

12

Ratio of Earnings to Fixed Charges

31

Certification of Thomas J. May, Chairman of Public Service Company of New Hampshire, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of Public Service Company of New Hampshire, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

32

Certification of Thomas J. May, Chairman of Public Service Company of New Hampshire, and James J. Judge, Executive Vice President and 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, dated November 6, 2015

Listing of Exhibits (WMECO)

12

Ratio of Earnings to Fixed Charges

31

Certification of Thomas J. May, Chairman of Western Massachusetts Electric Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

31.1

Certification of James J. Judge, Executive Vice President and Chief Financial Officer of Western Massachusetts Electric Company, required by Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, dated November 6, 2015

32

Certification of Thomas J. May, Chairman of Western Massachusetts Electric Company, and James J. Judge, Executive Vice President and 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, dated November 6, 2015

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

57

SIGNATURE

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

	EVERSOURCE ENERGY
November 6, 2015	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
November 6, 2015	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
November 6, 2015	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

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.

	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
November 6, 2015	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
November 6, 2015	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

59

EX-10.1

EXHIBIT 10.1

TWELFTH SUPPLEMENTAL INDENTURE

from

YANKEE GAS SERVICES COMPANY

doing business as EVERSOURCE ENERGY

to

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.

TRUSTEE

_________________________________

Dated as of September 1, 2015

Supplemental to Indenture of Mortgage

and Deed of Trust from

Yankee Gas Services Company to

The Bank of New York Mellon Trust Company, N.A. (formerly known as

The Bank of New York Trust Company, N.A., successor to

The Bank of New York, successor to
Fleet National Bank, formerly known as

The Connecticut National Bank), Trustee,

dated as of July 1, 1989, as amended and restated as of January 1, 2014

TWELFTH SUPPLEMENTAL INDENTURE

TWELFTH SUPPLEMENTAL INDENTURE, dated as of September 1, 2015, between YANKEE GAS SERVICES COMPANY, a specially chartered Connecticut corporation, doing business as Eversource Energy (herein called the “Company”), and THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A., a national banking corporation, successor as trustee to The Bank of New York, as successor to Fleet National Bank (formerly known as The Connecticut National Bank), as Trustee (the “Trustee”) under the Indenture of Mortgage and Deed of Trust, dated as of July 1, 1989, as amended and restated as of January 1, 2014, including any and all indentures and instruments supplemental thereto, including, without limitation, this Twelfth Supplemental Indenture, being herein called the “Indenture”);

WHEREAS, pursuant to Sections 201, 301, 401, 1301(b) and 1301(f) of the Indenture, the Company desires to provide for the issuance of a new series of Securities which Securities will be secured by and entitled to the benefits of the Indenture, and to add to its covenants and agreements contained in the Indenture certain other covenants and agreements; and

WHEREAS, all acts and things necessary to make this Twelfth Supplemental Indenture a valid, binding and legal instrument have been performed, and the issuance of the new series of Securities, subject to the terms of the Indenture, has been duly authorized by the Board of Directors of the Company and approved by the Connecticut Public Utilities Regulatory Authority (“PURA”), and the Company has requested and hereby requests the Trustee to enter into and join the Company in the execution and delivery of this Twelfth Supplemental Indenture;

NOW, THEREFORE, THIS TWELFTH SUPPLEMENTAL INDENTURE WITNESSETH, that, to secure the payment of the principal of (and premium, if any) and interest on the Outstanding Securities, including the new series of Securities hereunder issued, and the performance of the covenants therein and herein contained and to declare the terms and conditions on which all such Outstanding Securities are secured, and in consideration of the premises and of the purchase of the Securities by the Holders thereof, the Company by these presents does grant, bargain, sell, alien, remise, release, convey, assign, transfer, mortgage, hypothecate, pledge, set over and confirm to the Trustee, all property, rights, privileges and franchises of the Company of every kind and description, real, personal or mixed, tangible and intangible, whether now owned or hereafter acquired by the Company, wherever located, and grants a security interest therein for the purposes herein expressed, except any Excepted Property which is expressly excepted from the lien hereof in the Indenture, and including, without limitation, all property, rights, privileges and franchises particularly described in the Indenture, and eleven Supplemental Indentures thereto dated respectively as of April 1, 1992, December 1, 1992, June 1, 1995, April 1, 1997, January 1, 1999, January 1, 2004, November 1, 2004, July 1, 2005, October 1, 2008, April 1, 2010, and January 1, 2014, and, in addition, all the property, rights, privileges and franchises particularly described in Schedule A annexed to this Twelfth Supplemental Indenture, which are hereby made a part of, and deemed to be described herein, as fully as if set forth herein at length.

TO HAVE AND TO HOLD all said property, rights, privileges and franchises of every kind and description, real, personal or mixed, hereby and hereafter (by supplemental indenture or

otherwise) granted, bargained, sold, aliened, remised, released, conveyed, assigned, transferred, mortgaged, hypothecated, pledged, set over or confirmed as aforesaid, or intended, agreed or covenanted so to be, together with all the appurtenances thereto appertaining (said properties, rights, privileges and franchises, including any cash and securities hereafter deposited or required to be deposited with the Trustee (other than any such cash which is specifically stated herein not to be deemed part of the Mortgaged Property), being herein collectively called “Mortgaged Property”) unto the Trustee and its successors and assigns forever.

SUBJECT, HOWEVER, to Permitted Liens (as defined in Section 101 of the Indenture).

BUT IN TRUST, NEVERTHELESS, for the proportionate and equal benefit and security of the Holders from time to time of all the Outstanding Securities without any preference or priority of any such Security over any other such Security.

UPON CONDITION that, until the happening of an Event of Default (as defined in Section 901 of the Indenture) and subject to the provisions of Article Sixteen of the Indenture, the Company shall be permitted to possess and use the Mortgaged Property, except cash, securities and other personal property deposited and pledged, or required to be deposited and pledged, with the Trustee, and to receive and use the rents, issues, profits, revenues and other income of the Mortgaged Property.

AND IT IS HEREBY COVENANTED AND DECLARED that all the Series M Bonds are to be authenticated and delivered and the Mortgaged Property is to be held and applied by the Trustee, subject to the further covenants, conditions and trusts hereinafter set forth, and the Company does hereby covenant and agree to and with the Trustee, for the equal and proportionate benefit of all Holders of the Securities as follows:  

ARTICLE I

DEFINITIONS AND RULES OF CONSTRUCTION

Section 1.01.

Terms from the Indenture.  All defined terms used in this Twelfth Supplemental Indenture and not otherwise defined herein shall have the respective meanings ascribed to them in the Indenture.

Section 1.02.

References are to Twelfth Supplemental Indenture.  Unless the context otherwise requires, all references herein to “Articles,” “Sections” and other subdivisions are to the designated Articles, Sections and other subdivisions of this Twelfth Supplemental Indenture, and the words “herein,” “hereof,” “hereby,” “hereunder” and words of similar import refer to this Twelfth Supplemental Indenture as a whole and not to any particular Article, Section or other subdivision hereof or to the Indenture.

Section 1.03.

Consent to Amendment and Restatement of Indenture.  Each holder of a Series M Bond, solely by virtue of its acquisition thereof, including as an owner of a book-entry interest therein, shall have and be deemed to have consented,  without  the  need  for any  further

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action or consent by such holder, to the amendment and restatement of the Indenture in the form set forth in Exhibit B to the 11th Supplemental Indenture, dated as of January 1, 2014.

ARTICLE II

SERIES M BONDS

Section 2.01.

Designation; Amount.  There is hereby created and shall be outstanding under and secured by the Indenture a series of Securities entitled “First Mortgage Bonds, 3.35% Series M, Due 2025” (herein called the “Series M Bonds” or “Bonds”), limited in aggregate principal amount at any one time outstanding to Seventy-Five Million Dollars ($75,000,000).  

Section 2.02.

Form of Series M Bonds.  The form of the Series M Bonds shall be substantially as set forth in Exhibit A hereto with such insertions, omissions, substitutions and variations as may be determined by the officers executing the same as evidenced by their execution thereof.

The Series M Bonds shall be issued as fully registered Securities in denominations of $500,000 or any amount in excess thereof which is an integral multiple of $250,000 (except as may be necessary to reflect any principal amount not evenly divisible by $250,000 remaining after any partial redemption), or in such other denominations as the Trustee may approve.  The Series M Bonds shall be numbered M-1 and consecutively upwards, or in any other manner deemed appropriate by the Company.  

Section 2.03.

Provisions of Series M Bonds; Interest Accrual. The Series M Bonds shall mature on September 1, 2025, and shall bear interest, payable semiannually on the first day of March and September of each year, commencing March 1, 2016, at the rate of 3.35% per annum.  The interest on the Series M Bonds shall be payable without presentation of such Series M Bonds; and such interest to be paid only to or upon the written order of the registered Holders thereof of record at the applicable record date (as hereinafter defined).  The Series M Bonds shall be callable for redemption in whole or in part according to the terms and provisions herein in Article 2.  

Each Series M Bond authenticated in accordance with the terms of this Twelfth Supplemental Indenture shall be dated as of September 1, 2015 and shall bear interest on the principal amount thereof from such date until the maturity date unless redeemed pursuant to Section 2.05.  Interest on the Series M Bonds shall be computed on the basis of a 360-day year consisting of twelve 30-day months, and with respect to any such period less than a full month, on the basis of the actual number of days elapsed in such period.  

The person in whose name any Series M Bond is registered at the close of business on any record date with respect to any interest payment date shall be entitled to receive the interest payable on such interest payment date notwithstanding the cancellation of such Series M Bond upon any registration of transfer or exchange thereof subsequent to the record date and prior to such interest payment date, except that if and to the extent the Company shall default in the payment of the interest due on such interest payment date,  then  such defaulted interest  shall  be

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paid to the person in whose name such Series M Bond is registered on the Business Day immediately preceding the date of such payment.  The term “record date” as used in this Section with respect to any regular interest payment (i.e. March 1 or September 1) shall mean the February 15 or August 15, as the case may be, next preceding such interest payment date, or if such February 15 or August 15 shall be a legal holiday or a day on which banking institutions in the Borough of Manhattan, New York, New York are authorized by law to close, the next preceding day which shall not be a legal holiday or a day on which such institutions are so authorized to close.

Notwithstanding the otherwise applicable provisions of the Indenture, the principal and the redemption price of, and interest on, the Series M Bonds shall be payable by Federal funds bank wire transfer of immediately available funds so long as required by Section 5.1 of the Bond Purchase Agreements, each dated September 10, 2015, between the Company and the initial purchasers of the Series M Bonds (the “Bond Purchase Agreements”) or, in the event such section shall no longer be applicable, at the office or agency of the Company in New York, New York, in such coin or currency of the United States of America as at the time of payment is legal tender for public or private debts.

Section 2.04.

No Sinking Fund; No Mandatory Scheduled Redemptions Prior to Final Maturity.  The Series M Bonds shall not be subject to any sinking fund or mandatory scheduled redemption prior to final maturity.

Section 2.05.

Optional Redemption.  The Series M Bonds are subject to redemption at the option of the Company, prior to maturity, as a whole at any time or in part from time to time, in accordance with the provisions of the Indenture, upon not less than thirty (30) days’ and not more than sixty (60) days’ prior notice (which notice may be made subject to the deposit of redemption moneys with the Trustee before the date fixed for redemption).  Such notice shall specify (a) the date of such redemption, (b) the principal amount of the Holder’s Bond to be redeemed on such date, (c) that a premium may be payable, (d) the estimated premium, calculated as of the day such notice is given and (e) the accrued interest applicable to such redemption.  Such notice of redemption shall also certify all facts, if any, which are conditions precedent to any such redemption and shall conform to the requirements in the Indenture.  Notice of redemption having been so given, the aggregate principal amount of the Series M Bonds specified in such notice, together with accrued interest thereon, and the premium, if any, payable with respect thereto shall become due and payable on the redemption date specified in such notice (unless the notice is made subject to the deposit of redemption moneys with the Trustee before the date fixed for redemption).  Two Business Days prior to the redemption date specified in such notice of optional redemption, the Company shall provide the Trustee and each Holder of a Series M Bond written notice of whether or not any premium is payable in connection with such redemption, the premium, if any, calculated as of the second Business Day prior the redemption date, and a reasonably detailed computation of the Make-Whole Amount (as defined in Section 2.06).  If the Company elects to redeem the Series M Bonds prior to the Par Call Date (as defined in Section 2.06), it will do so at a redemption price equal to the principal amount of the Series M Bonds being prepaid plus accrued interest thereon to the date of such redemption together with a premium equal to the then applicable Make-Whole Amount.  If the Company elects to redeem the Series M Bonds on or after the Par Call Date, it  will  do so at  a  redemption

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price equal to one hundred percent (100%) of the principal amount of the Series M Bonds being redeemed, plus accrued and unpaid interest thereon to, but excluding, the redemption date.  The redemption price will be calculated assuming a 360-day year consisting of twelve 30-day months.

If the Company elects to redeem less than all of the Series M Bonds, the Trustee shall select on a pro rata basis the particular Series M Bonds, or portions of them, to be redeemed.  

Notice of redemption shall be given to the Holder of the Series M Bonds.  On and after the date of redemption of the Series M Bonds (unless the Company defaults in the payment of the redemption price and interest accrued thereon to such date), interest on the Series M Bonds, or the portions of them so called for redemption, shall cease to accrue.  

The Series M Bonds are not otherwise subject to redemption.  

Section 2.06.

Definitions Applicable to Redemption Provisions.  

The “Make-Whole Amount,” as calculated by the Company, shall mean, with respect to any Series M Bond, an amount equal to the excess, if any, of the Discounted Value of the Remaining Scheduled Payments through the Par Call Date with respect to the Called Principal of such Bond over the amount of such Called Principal, provided that the Make-Whole Amount may in no event be less than zero.

The “Called Principal” means, with respect to any Series M Bond, the principal of such Series M Bond that is to be prepaid or has become or is declared to be immediately due and payable pursuant to Section 2.05, as the context requires.

The “Discounted Value” means, with respect to the Called Principal of any Bond, the amount obtained by discounting all Remaining Scheduled Payments through the Par Call Date with respect to such Called Principal from their respective scheduled due dates to the Settlement Date with respect to such Called Principal, in accordance with accepted financial practice and at a discount factor (applied on the same periodic basis as that on which interest on the Notes is payable) equal to the Reinvestment Yield with respect to such Called Principal.

The “Par Call Date” means the date that is three months prior to the maturity date of the Series M Bonds.  

The “Reinvestment Yield” means, with respect to the Called Principal of any Bond, 0.50% over the yield to maturity implied by the yield(s) reported as of 10:00 a.m. (New York City time) on the second Business Day preceding the Settlement Date with respect to such Called Principal, on the display designated as “Page PX1”  (or such other display as may replace Page PX1) on Bloomberg Financial Markets for the most recently issued actively traded on-the-run U.S. Treasury securities (“Reported”) having a maturity equal to the Remaining Average Life of such Called Principal as of such Settlement Date. If there are no such U.S. Treasury securities Reported having a maturity equal to such Remaining Average Life, then such implied yield to maturity will be determined by (a) converting U.S. Treasury bill quotations to bond equivalent yields in accordance with accepted financial practice and (b) interpolating linearly between the

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yields Reported for the applicable most recently issued actively traded on-the-run U.S. Treasury securities with the maturities (1) closest to and greater than such Remaining Average Life and (2) closest to and less than such Remaining Average Life. The Reinvestment Yield shall be rounded to the number of decimal places as appears in the interest rate of the applicable Bond.

If such yields are not Reported or the yields Reported as of such time are not ascertainable (including by way of interpolation), then “Reinvestment Yield” means, with respect to the Called Principal of any Series M Bond, 0.50% over the yield to maturity implied by the U.S. Treasury constant maturity yields reported, for the latest day for which such yields have been so reported as of the second Business Day preceding the Settlement Date with respect to such Called Principal, in Federal Reserve Statistical Release H.15 (or any comparable successor publication) for the U.S. Treasury constant maturity having a term equal to the Remaining Average Life of such Called Principal as of such Settlement Date. If there is no such U.S. Treasury constant maturity having a term equal to such Remaining Average Life, such implied yield to maturity will be determined by interpolating linearly between (1) the U.S. Treasury constant maturity so reported with the term closest to and greater than such Remaining Average Life and (2) the U.S. Treasury constant maturity so reported with the term closest to and less than such Remaining Average Life. The Reinvestment Yield shall be rounded to the number of decimal places as appears in the interest rate of the applicable Bond.

The “Remaining Average Life” means, with respect to any Called Principal, the number of years obtained by dividing (i) such Called Principal into (ii) the sum of the products obtained by multiplying (a) the principal component of each Remaining Scheduled Payment through the Par Call Date with respect to such Called Principal by (b) the number of years, computed on the basis of a 360-day year composed of twelve 30-day months and calculated to two decimal places, that will elapse between the Settlement Date with respect to such Called Principal and the scheduled due date of such Remaining Scheduled Payment through the Par Call Date.

The “Remaining Scheduled Payments” means, with respect to the Called Principal of any Bond, all payments of such Called Principal and interest thereon that would be due after the Settlement Date with respect to such Called Principal if no payment of such Called Principal were made prior to its scheduled due date, provided that if such Settlement Date is not a date on which interest payments are due to be made under the Bonds, then the amount of the next succeeding scheduled interest payment will be reduced by the amount of interest accrued to such Settlement Date and required to be paid on such Settlement Date.

The “Settlement Date” means, with respect to the Called Principal of any Bond, the date on which such Called Principal is to be prepaid or has become or is declared to be immediately due and payable pursuant to Section 2.05, as the context requires.

The principal amount, if any, of the Series M Bonds to be redeemed pursuant to this Section 2.05 shall be selected on a pro rata basis from all Series M Bonds Outstanding on the date of redemption.

The Series M Bonds shall not be redeemable at the option of the Company prior to their Stated Maturity other than as provided in Section 2.05.

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All calculations hereunder shall be the responsibility of the Company.  

Section 2.07.

Place of Payment.  The principal and the redemption price of, and the premium, if any, and the interest on, the Series M Bonds shall be payable at the corporate trust office of The Bank of New York Mellon Trust Company, N.A., in New York, New York.

Section 2.08.

Transfer and Exchange of Series M Bonds.  The Series M Bonds may be surrendered for registration of transfer as provided in Section 305 of the Indenture at the office or agency of the Company in the Borough of Manhattan, New York, New York, and may be surrendered at said office for exchange for a like aggregate principal amount of Series M Bonds of other authorized denominations.  Notwithstanding the provisions of Section 305 of the Indenture, no charge, except for taxes or other governmental charges, shall be made by the Company for any registration of transfer of Series M Bonds or for the exchange of Series M Bonds for Securities of other authorized denominations.  

Section 2.09.

Bond Purchase Agreements.  Reference is made to Sections 5 and 7 of the Bond Purchase Agreements for certain provisions governing the rights and obligations of the Company, the Trustee and the Holders of the Series M Bonds.  Such provisions are deemed to be incorporated in this Article II by reference as if set forth herein at length.

Section 2.10.

Restrictions on Transfer.  All Series M Bonds originally issued hereunder shall bear the following legend:

THIS SECURITY HAS NOT BEEN REGISTERED UNDER THE SECURITIES ACT OF 1933, AS AMENDED (THE “1933 ACT”).  THE HOLDER HEREOF, BY PURCHASING THIS SECURITY, AGREES FOR THE BENEFIT OF YANKEE GAS SERVICES COMPANY DOING BUSINESS AS EVERSOURCE ENERGY (THE “COMPANY”) AND PRIOR HOLDERS THAT THIS SECURITY MAY BE OFFERED, RESOLD, PLEDGED OR OTHERWISE TRANSFERRED ONLY (1) TO THE COMPANY (UPON REDEMPTION THEREOF OR OTHERWISE), (2) SO LONG AS THIS SECURITY IS ELIGIBLE FOR RESALE PURSUANT TO RULE 144A, TO A PERSON WHO THE SELLER REASONABLY BELIEVES IS A QUALIFIED INSTITUTIONAL BUYER, WITHIN THE MEANING OF RULE 144A UNDER THE 1933 ACT, IN A TRANSACTION MEETING THE REQUIREMENTS OF RULE 144A, (3) IN AN OFFSHORE TRANSACTION IN ACCORDANCE WITH REGULATION S UNDER THE 1933 ACT, (4) PURSUANT TO AN EXEMPTION FROM REGISTRATION IN ACCORDANCE WITH RULE 144 (IF AVAILABLE) UNDER THE 1933 ACT, (5) IN RELIANCE ON ANOTHER EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE 1933 ACT, SUBJECT TO THE RECEIPT BY THE COMPANY OF AN OPINION OF COUNSEL TO THE EFFECT THAT SUCH TRANSFER  IS  EXEMPT FROM  THE  REGISTRATION REQUIREMENTS OF THE 1933 ACT OR (6) PURSUANT TO AN EFFECTIVE REGISTRATION STATEMENT UNDER THE 1933 ACT, SUBJECT (IN THE CASE OF CLAUSES (2), (3), (4) AND (5)) TO THE RECEIPT    BY   THE    COMPANY   OF    A    CERTIFICATION   OF     THE

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TRANSFEROR TO THE EFFECT THAT SUCH TRANSFER IS IN COMPLIANCE WITH THE 1933 ACT, AND IN EACH CASE IN ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF ANY JURISDICTION OF THE UNITED STATES.  THE HOLDER OF THIS SECURITY WILL, AND EACH SUBSEQUENT HOLDER IS REQUIRED TO, NOTIFY ANY PURCHASER OF THIS SECURITY FROM IT OF THE RESALE RESTRICTIONS REFERRED TO HEREIN.  

All Series M Bonds issued upon transfer or exchange thereof shall bear such legend unless the Company shall have delivered to the Trustee an Opinion of Counsel which states that the Series M Bonds may be issued without such legend.  All Series M Bonds issued upon transfer or exchange of a Series M Bond or Series M Bonds which do not bear such legend shall be issued without such legend.  The Company may from time to time modify the foregoing restrictions on resale and other transfers, without the consent of but upon notice to the Holders, in order to reflect any amendment to Rule 144A under the Securities Act of 1933 or change in the interpretation thereof or practices thereunder.

Section 2.11.

Authentication and Delivery.  Upon the execution of this Twelfth Supplemental Indenture, the Series M Bonds shall be executed by the Company and delivered to the Trustee for authentication, and thereupon the same shall be authenticated and delivered by the Trustee pursuant to and upon a Company Request.

Section 2.12.

Default.  Pursuant to the Indenture (and notwithstanding any provision of Section 901 thereof to the contrary), for purposes of determining whether an Event of Default exists with respect to the Series M Bonds, any default in payment (whether due as a scheduled installment of principal or interest, or at original maturity or earlier redemption or acceleration, or otherwise) with respect to Securities of any other series which constitutes an Event of Default with respect to the Securities of such series shall also constitute an Event of Default with respect to the Series M Bonds.

ARTICLE III

AMENDMENT OF INDENTURE

Section 3.01.

Consent and Amendment to Section 1003 of the Indenture.  (a) Each holder of a Series M Bond, solely by virtue of its acquisition thereof, including as an owner of a book-entry interest therein, shall have and be deemed to have consented, without the need for any further action or consent by such holder, to the amendment of the Indenture by deleting “and” at the end of Section 1003(i), deleting the period at the end of Section 1003(j), adding “;” at the end of Section 1003(j), and adding the following clauses at the end of Section 1003 of the Indenture:

"(k)

in no event shall the Trustee be responsible or liable for special, indirect, or consequential or loss or damage of any kind whatsoever (including, but not limited to,   loss of profit) irrespective of whether the Trustee has been advised of the likelihood of   such loss or damage and regardless of the form of action; and

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(l)

in no event shall the Trustee be responsible or liable for any failure or delay in the performance of its obligations hereunder arising out of or caused by, directly or indirectly, forces beyond its control, including, without limitation, strikes, work stoppages, accidents, acts of war or terrorism, civil or military disturbances, nuclear or natural catastrophes or acts of God, and interruptions, loss or malfunctions of utilities, communications or computer (software and hardware) services.”  

(b)  The amendments contained in this Section 3.01 shall apply to and be effective with respect to the Series M Bonds from and after the Issue Date thereof.  The amendments contained in this Section 3.01 shall not become effective with respect to any other series of Securities until such series consents thereto or otherwise in accordance with Section 1302 of the Indenture.

Section 3.02.

Consent and Amendment of the Indenture by Adding Section 117.  (a) Each holder of a Series M Bond, solely by virtue of its acquisition thereof, including as an owner of a book-entry interest therein, shall have and be deemed to have consented, without the need for any further action or consent by such holder, to the amendment of the Indenture by adding the following Section 117:

“SECTION 117

WAIVER OF JURY TRIAL.

EACH OF THE COMPANY AND THE TRUSTEE HEREBY IRREVOCABLY WAIVES, TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, ANY AND ALL RIGHT TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO THIS MORTGAGE, THE SECURITIES OR THE TRANSACTION CONTEMPLATED HEREBY.”

(b)  The amendments contained in this Section 3.02 shall apply to and be effective with respect to the Series M Bonds from and after the issuance thereof.  The amendments contained in this Section 3.02 shall not become effective with respect to any other series of Securities until such series consents thereto or otherwise in accordance with Section 1302 of the Indenture.

Section 3.03.

Amendment of the Indenture by Adding Section 118.  (a)  The Indenture is hereby amended by adding the following Section 118:

“SECTION 118

FOREIGN ACCOUNT TAX COMPLIANCE ACT (FATCA).

In order to comply with applicable tax laws, rules and regulations (inclusive of directives, guidelines and interpretations promulgated by competent authorities) in effect from time to time (“Applicable Law”) a foreign financial institution, issuer, trustee, paying agent, holder or other institution is or has agreed to be subject to related to this Mortgage, the Company agrees (i) to provide to the Bank of New York Mellon Trust Company, N.A. sufficient information about the transaction (including any modification to the terms of such transaction) so The Bank of New York Mellon Trust Company, N.A. can determine whether it has tax related obligations under Applicable Law, and (ii) that The Bank of New York Mellon Trust Company, N.A. shall be entitled to make any withholding or deduction from payments under this Mortgage

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to the extent necessary to comply with Applicable Law for which The Bank of New York Mellon Trust Company, N.A. shall not have any liability.  The terms of this section shall survive the termination of this Mortgage.”  

(b)  The amendments contained in this Section 3.03 shall apply to and be effective as to all series of Securities as of the execution of this Supplemental Indenture.

ARTICLE IV

MISCELLANEOUS PROVISIONS

Section 4.01.

Effectiveness and Ratification of Indenture.  The provisions of this Twelfth Supplemental Indenture shall be effective from and after the execution hereof; and the Indenture, as hereby supplemented, shall remain in full force and effect.

Section 4.02.

Titles.  The titles of the several Articles and Sections of this Twelfth Supplemental Indenture shall not be deemed to be any part thereof, are inserted for convenience only and shall not affect any interpretation hereof.

Section 4.03.

Acceptance of Trust; Not Responsible for Recitals, Etc.  The Trustee hereby accepts the trusts herein declared, provided, created or supplemented and agrees to perform the same upon the terms and conditions herein and in the Indenture, as heretofore supplemented, set forth and upon the following terms and conditions:

The Trustee shall not be responsible in any manner whatsoever for or in respect of the validity or sufficiency of this Twelfth Supplemental Indenture or for or in respect of the recitals contained herein, all of which recitals are made by the Company solely.  In general, each and every term and condition contained in Article Ten of the Indenture shall apply to and form part of this Twelfth Supplemental Indenture with the same force and effect as if the same were herein set forth in full with such omissions, variations and insertions, if any, as may be appropriate to make the same conform to the provisions of this Twelfth Supplemental Indenture.

Section 4.04.

Successors and Assigns.  All covenants, provisions, stipulations and agreements in this Twelfth Supplemental Indenture contained are and shall be for the sole and exclusive benefit of the parties hereto, their successors and assigns, and (subject to the provisions of the Bond Purchase Agreements) of the Holders and registered owners from time to time of the Securities issued and outstanding under and secured by the Indenture (except that the provisions of Article II hereof are and shall be for the sole and exclusive benefit of the Holders of the Series M Bonds).

Section 4.05.

Counterparts.  This Twelfth Supplemental Indenture may be executed in any number of counterparts, each of which so executed shall be deemed to be an original, and all such counterparts shall together constitute but one and the same instrument.

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Section 4.06.

Governing Law.  The laws of the State of Connecticut shall govern this Twelfth Supplemental Indenture and the Series M Bonds, except to the extent that the validity or perfection of the lien of the Indenture, or remedies thereunder, are governed by the laws of a jurisdiction other than the State of Connecticut; provided however that the rights and obligations of the Trustee shall be governed by the laws of the state in which the Corporate Trust Office is located.  

[THE REMAINDER OF THIS PAGE LEFT BLANK INTENTIONALLY]

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IN WITNESS WHEREOF, the parties hereto have caused this Twelfth Supplemental Indenture to be duly executed, sealed and attested as of the day and year first above written.

YANKEE GAS SERVICES COMPANY

doing business as EVERSOURCE ENERGY

By:

/S/ PHILIP J. LEMBO                     

Philip J. Lembo

Vice President and Treasurer

Executed, sealed and delivered by

YANKEE GAS SERVICES COMPANY

doing business as EVERSOURCE ENERGY

in the presence of:

/S/ RICHARD J. MORRISON       

/S/ MATTHEW J. BENSON         

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A., as Trustee

By:

/S/ TERESA PETTA                          

Name:  Teresa Petta

Title:    Vice President

Executed, sealed and delivered by

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.,

as Trustee, in the presence of:

/S/ VALERE D. BOYD, VP            

/S/ DANIEL MARROQUIN, VP    

COMMONWEALTH OF MASSACHUSETTS

)

)  ss.:  Westwood

COUNTY OF NORFOLK

)

On this   9   day of          September              , 2015, before the undersigned officer, personally appeared Philip J. Lembo, who acknowledged himself to be the Vice President and Treasurer of Yankee Gas Services Company, a Connecticut corporation, doing business as Eversource Energy, and that they, as such officers, being authorized so to do, executed the foregoing instrument for the purpose therein contained, by signing the name of the corporation by themselves as such officers, and as their free act and deed.

IN WITNESS WHEREOF, I hereunto set my hand and official seal.

/S/ BARBARA J. MURPHY                      

Notary Public

My commission expires:   March 30, 2018  .

(SEAL)  

ACKNOWLEDGMENT

A notary public or other officer completing this

certificate verifies only the identity of the individual

who signed the document to which this certificate is

attached, and not the truthfulness, accuracy, or validity

of that document.

State of California

County of Los Angeles

On  9/4/2015                  

 before me, Cynthia Cerda, Notary Public                 

(insert name and title of the officer)

Personally appeared Teresa Petta, who proved to me on the basis of satisfactory evidence to be the person whose name is subscribed to the within instrument and acknowledged to me that she executed the same in her authorized capacity, and that by her signature on the instrument the person, or the entity upon behalf of which the person acted, executed the instrument.

I certify under PENALTY OF PERJURY under the laws of the State of California that the foregoing paragraph is true and correct.  

WITNESS my hand and official seal.  

Signature /S/ CYNTHIA CERDA         

(Seal)  

SCHEDULE A

ALL THE PROPERTY, RIGHTS, PRIVILEGES AND FRANCHISES AS SET FORTH IN THE FOLLOWING DESCRIPTIONS.

EXHIBIT A

[FORM OF FIRST MORTGAGE BOND, 3.35% SERIES M, DUE 2025]

THIS SECURITY HAS NOT BEEN REGISTERED UNDER THE SECURITIES ACT OF 1933, AS AMENDED (THE “1933 ACT”).  THE HOLDER HEREOF, BY PURCHASING THIS SECURITY, AGREES FOR THE BENEFIT OF YANKEE GAS SERVICES COMPANY DOING BUSINESS AS EVERSOURCE ENERGY (THE “COMPANY”) AND PRIOR HOLDERS THAT THIS SECURITY MAY BE OFFERED, RESOLD, PLEDGED OR OTHERWISE TRANSFERRED ONLY (1) TO THE COMPANY (UPON REDEMPTION THEREOF OR OTHERWISE), (2) SO LONG AS THIS SECURITY IS ELIGIBLE FOR RESALE PURSUANT TO RULE 144A, TO A PERSON WHO THE SELLER REASONABLY BELIEVES IS A QUALIFIED INSTITUTIONAL BUYER, WITHIN THE MEANING OF RULE 144A UNDER THE 1933 ACT, IN A TRANSACTION MEETING THE REQUIREMENTS OF RULE 144A, (3) IN AN OFFSHORE TRANSACTION IN ACCORDANCE WITH REGULATION S UNDER THE 1933 ACT, (4) PURSUANT TO AN EXEMPTION FROM REGISTRATION IN ACCORDANCE WITH RULE 144 (IF AVAILABLE) UNDER THE 1933 ACT, (5) IN RELIANCE ON ANOTHER EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE 1933 ACT, SUBJECT TO THE RECEIPT BY THE COMPANY OF AN OPINION OF COUNSEL TO THE EFFECT THAT SUCH TRANSFER IS IN COMPLIANCE WITH THE 1933 ACT OR (6) PURSUANT TO AN EFFECTIVE REGISTRATION STATEMENT UNDER THE 1933 ACT, SUBJECT (IN THE CASE OF CLAUSES (2), (3), (4) AND (5)) TO THE RECEIPT BY THE COMPANY OF A CERTIFICATION OF THE TRANSFEROR TO THE EFFECT THAT SUCH TRANSFER IS EXEMPT FROM THE REGISTRATION REQUIREMENTS OF THE 1933 ACT, AND IN EACH CASE IN ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF ANY JURISDICTION OF THE UNITED STATES.  THE HOLDER OF THIS SECURITY WILL, AND EACH SUBSEQUENT HOLDER IS REQUIRED TO, NOTIFY ANY PURCHASER OF THIS SECURITY FROM IT OF THE RESALE RESTRICTIONS REFERRED TO HEREIN.

Yankee Gas Services Company

doing business as Eversource Energy

First Mortgage Bonds,

3.35% Series M, Due 2025

CUSIP Number:

No. M - [      ]

Principal Amount:  $[

]

Stated Maturity of Principal:  September 1, 2025

Applicable Rate:   3.35%

Interest Payment Dates:

March 1 and September 1, commencing March 1, 2016 and at the Stated Maturity of the principal

Yankee Gas Services Company, doing business as Eversource Energy, a specially chartered Connecticut corporation (hereinafter called the “Company”, which term includes any successor corporation under the Indenture hereinafter referred to), for value received, hereby promises to  pay to  [___________],  or registered  assigns,  at  the Stated Maturity set forth above, the Principal Amount set forth above (or so much thereof as shall not have been paid upon prior redemption) and to pay interest (computed on the basis of  a  360-day year of twelve  30-day  months) thereon from the date of issuance hereof or from the most recent  Interest  Payment  Date  to which interest has been paid or duly provided for, on each Interest Payment Date set forth above in each year at the Applicable Rate set forth above.  The interest so payable, and punctually paid or duly provided for, on any Interest Payment Date will, as provided in said Indenture, be paid to the Person in whose name this Bond (or one or more Predecessor Securities, as  defined  in  said  Indenture)  is  registered at the close of business on the Regular Record Date for such interest, which shall be the 1st day  of the calendar month next preceding such Interest Payment Date (or if such 1^st day shall be a legal holiday or a day on which banking institutions in the Borough of Manhattan, New York, New York are authorized by law to close, the next preceding day which shall  not  be  a  legal holiday or a day on which such institutions are so authorized to close).  Any such interest not so punctually paid or duly provided for shall be paid to the Person in whose name this Bond is registered on the Business Day immediately preceding the date of such payment.   If  all  or any portion of  the  principal of, or the premium (if any) or interest on, this Bond shall not be paid when due, the amount not so paid shall bear interest at the lesser of (x) the highest rate allowed by applicable law or (y) the greater of (i) the Prime Rate (as defined in the Bond Purchase Agreements) or  (ii)  the Applicable Rate plus 1% per annum.

The principal and the Redemption Price of, and  the  interest  on, this Bond shall be payable at the principal corporate trust office  of  The  Bank  of  New York  Mellon Trust  Company, N.A., in New York, New York.  All such payments shall be made in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts.

This Series  M  Bond is one of a duly authorized issue of Bonds of the Company designated as its “First Mortgage Bonds” (herein called the “Bonds”), issued and to be issued in one or more series under, and all equally and ratably secured by, an Indenture of Mortgage and Deed of Trust, dated as of July  1,  1989, as amended and restated as of January  1,  2014 (herein, together with  eleven Supplemental Indentures thereto dated respectively as of April 1, 1992, December 1, 1992, June 1, 1995, April 1, 1997, January 1, 1999, January 1, 2004, November 1, 2004, July 1, 2005, October  1,  2008, April  1,  2010, January 1, 2014, and the Twelfth Supplemental Indenture, dated as of September 1, 2015 (the “Twelfth Supplemental Indenture”), called the “Indenture”), between the Company and The Bank of New York Mellon Trust Company, N.A.,  (formerly  known  as  The Bank of New York Trust Company, N.A.), successor as trustee to  The  Bank  of New York, successor to Fleet National Bank (formerly known as The Connecticut National Bank), as Trustee (herein called the “Trustee,” which term includes any successor Trustee under the Indenture).  Reference is hereby made to the Indenture for a description of the properties thereby mortgaged, pledged and assigned, the nature and extent of the security, the respective rights thereunder of the Holders of the Bonds, the Trustee and the Company, and the terms upon which the Bonds are, and are to be, authenticated and delivered.  All  capitalized  terms used  in  this Bond which are not defined herein shall have the respective meanings  ascribed thereto  in  the Indenture.  Reference is also made to the Bond Purchase Agreements, as defined in  the  Twelfth  Supplemental Indenture, for a further description of the respective rights of the Holders of the Series  M  Bonds, the Company and the Trustee, and the terms applicable to the Series M Bonds.

As provided in the Indenture, the Bonds are issuable in series which may vary as in the Indenture provided or permitted.  This Series M Bond is one of the series specified in its title.

The  Series  M  Bonds  are  not  subject to any sinking fund or mandatory scheduled redemption prior to final maturity.

The Series M Bonds are subject to redemption at the option of the Company, prior to maturity, as a whole at any time or in part from time to time, in accordance with  the  provisions  of the Indenture, upon not less than thirty (30) days’ and not more than sixty (60) days’ prior notice (which notice may be made subject to the deposit  of  redemption  moneys  with  the Trustee before the date fixed for redemption).  Such notice shall specify (a) the date of such redemption, (b) the principal amount of the Holder’s Bond to be redeemed on such date, (c) that a premium may be payable,  (d)  the estimated premium, calculated as of the day such notice is given and  (e)  the accrued interest applicable to such redemption.    Such notice of redemption shall also certify  all facts, if  any, which are conditions precedent to any such redemption and shall conform to the requirements in the Indenture.  Notice of redemption having been so given, the aggregate principal amount of the Series M Bonds specified in such notice, together with accrued interest thereon, and the premium, if any, payable with respect thereto shall become due and payable on the redemption date specified in such notice (unless the notice is made subject to the deposit of redemption moneys with the Trustee before the date fixed for redemption).  Two Business Days prior to the redemption date specified in such notice of optional redemption, the  Company shall  provide  the Trustee and each Holder of a Series M Bond written notice of whether or not any premium is payable in connection with such redemption, the premium, if any, calculated as of the second Business Day prior the redemption date, and a reasonably detailed computation of the Make-Whole Amount (as defined below).   If the Company elects to redeem the Series  M  Bonds prior to the Par Call Date (as

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defined below), it will do so at a redemption price equal to the principal amount of the Series M Bonds being prepaid plus accrued interest thereon to the date of such redemption together with a premium equal to the then applicable Make-Whole Amount.  If the Company elects to redeem the Series  M  Bonds  on or after the Par Call Date, it will do so at a redemption price equal to one hundred percent (100%) of  the principal amount of the Series  M  Bonds being redeemed, plus accrued and unpaid interest thereon to, but excluding, the redemption date.  The redemption price will be calculated assuming a 360-day year consisting of twelve 30-day months.

If the Company elects to redeem less than all of the Series M Bonds, the Trustee shall select on a pro rata basis the particular Series M Bonds, or portions of them, to be redeemed.  

Notice of redemption shall be given to the Holder of the Series M Bonds.  On and after the Redemption Date (unless the Company defaults in the payment of the redemption price and interest accrued thereon to such date), interest on the Series M Bonds, or the portions of them so called for redemption, shall cease to accrue.  

The Series M Bonds are not otherwise subject to redemption.  

The “Make-Whole Amount,” as calculated by the Company, shall  mean, with  respect  to any Series  M  Bond, an  amount equal to  the excess, if any, of the Discounted Value of the Remaining Scheduled Payments through the Par Call Date with respect to the Called Principal of such  Bond  over  the  amount  of  such Called  Principal, provided that  the Make-Whole Amount may in no event be less than zero.

The “Called Principal” means, with respect to any Series M Bond, the principal of such Series  M  Bond that  is  to be prepaid  or has become or is declared to be immediately due and payable pursuant to Section 2.05 of the Twelfth Supplemental Indenture, as the context requires.

The “Discounted Value” means, with respect to the Called Principal of any Bond, the amount obtained by discounting all Remaining Scheduled Payments through the Par Call Date with respect to such Called Principal from their respective scheduled due dates to the Settlement Date with respect to such Called Principal, in accordance with accepted financial practice and at a discount factor (applied on the same periodic basis as that on which interest on the Notes is payable) equal to the Reinvestment Yield with respect to such Called Principal.

The “Par Call Date” means the date that is three months prior to the maturity date of the Series M Bonds.  

The  “Reinvestment Yield”  means, with   respect  to  the  Called Principal of any Bond, 0.50% over  the  yield  to  maturity  implied by the yield(s) reported as of  10:00 a.m.   (New  York City time) on the second Business Day preceding the Settlement Date with respect to such Called Principal, on the display designated as “Page PX1”  (or  such  other  display  as  may replace Page PX1) on Bloomberg Financial Markets  for  th e most  recently  issued actively traded on-the-run U.S. Treasury securities (“Reported”) having  a  maturity  equal  to  the Remaining Average Life of such Called Principal as of such Settlement Date. If there are no such U.S. Treasury securities Reported  having  a  maturity  equal  to such  Remaining  Average  Life, then  such  implied  yield  to

A-3

maturity will be determined by  (a ) converting  U.S.  Treasury  bill quotations to bond equivalent yields in accordance with accepted financial practice and  (b)  interpolating  linearly  between the yields Reported for the applicable most recently issued actively traded on-the-run U.S. Treasury securities with the maturities  (1)  closest to  and greater than such  Remaining  Average  Life  and  (2)  closest to and less than such Remaining Average Life. The  Reinvestmen t Yield  shall  be rounded to  the  number of decimal places as appears in the interest rate of the applicable Bond.

If  such  yields  are  not Reported  or  the yields Reported as of such time are not ascertainable  (including  by  way of interpolation),  then  “Reinvestment Yield”  means,  with respect to the Called Principal of any  Series M  Bond,  0.50%  over  the  yield  to maturity implied by the U.S. Treasury constant  maturity  yields  reported, for  the  latest  day  for  which such yields have been so reported as  of  the second  Business  Day  preceding  the Settlement Date with  respect to  such  Called  Principal, in  Federal  Reserve  Statistical  Release H.15  (or  any  comparable  successor  publication)  for  the  U.S. Treasury constant maturity having a term equal to the Remaining Average Life of such Called Principal as of such Settlement Date. If there is  no  such  U.S.  Treasury  constant  maturity having  a  term  equal  to  such  Remaining  Average  Life, such  implied yield to maturity will be determined by  interpolating  linearly  between  (1)  the  U.S. Treasury constant maturity so reported with the term closest to and greater than such Remaining Average Life and  (2)  the  U.S. Treasury  constant maturity so reported with the term closest to and less than such Remaining  Average  Life.   The Reinvestment Yield shall be rounded to the number of decimal places as appears in the interest rate of the applicable Bond.

The  “Remaining  Average  Life”  means,  with respect to  any Called Principal,  the  number of years obtained by dividing  (i)  such Called  Principal  into (ii)  the  sum  of  the products obtained by multiplying  (a)  the principal component of each  Remaining  Scheduled  Payment through the Par Call Date with respect to such Called Principal by  (b)  the  number of  years, computed on the basis of a 360-day year composed of twelve 30-day months and calculated to two decimal places, that will elapse between the  Settlement  Date  with respect  to  such Called  Principal and the scheduled due date of such Remaining Scheduled Payment through the Par Call Date.

The “Remaining Scheduled Payments” means, with respect to the Called Principal of any Bond, all payments of such Called Principal and interest thereon that would be due after the Settlement Date with  respect  to such Called  Principa l if  no  payment  of  such  Called  Principal were made prior to its scheduled due date, provided that if such Settlement Date is not a date on which interest  payments are  due  to  be  made  under  the  Bonds, then  the  amount  of  the  next succeeding scheduled interest payment will be reduced by the amount of interest accrued to such Settlement Date and required to be paid on such Settlement Date.

The  “Settlement Date”  means, with respect  to  the  Called  Principal  of any Bond, the date on which such Called Principal  is  to  be  prepaid  or has become or is declared to be immediately due and payable pursuant to Section 2.05 of the Twelfth Supplemental Indenture, as the context requires.

If an Event of Default, as defined in the Indenture, shall occur, the principal of the Series M Bonds may become or be declared due and payable in the manner and with the effect provided in the Indenture and the Bond Purchase Agreements.

A-4

The Indenture permits, with certain exceptions as therein provided, the amendment thereof and  the  modification  of  the  rights  and obligations of the Company and the rights of the Holders of the Bonds under the Indenture at any time by the Company with the consent of the Holders of a majority  in  aggregate principal  amount  of  the  Bonds of  all series at the time Outstanding affected by such modification.  The Indenture also contains provisions permitting the Holders of specified percentages  in  principal  amount  of  Bonds  at  the  time Outstanding on behalf of the Holders of all the  Bonds, to  waive  compliance  by  the  Company  with certain provisions of the Indenture and certain  past  defaults  under the  Indenture  and  their  consequences.  Any  such  consent  or  waiver agreed to as set forth above by the Holder of this Bond shall be conclusive and binding upon such Holder and upon all future Holders of this Bond and of any Bond issued upon the transfer hereof or in  exchange  hereof  or  in  lieu hereof, whether or not notation of such consent or waiver is made upon this Bond.

No  reference  herein  to  the  Indenture  and  no  provision of this Bond or of the Indenture shall  alter  or  impair  the  obligation  of  the  Company, which is absolute and unconditional, to pay the principal of (and premium, if any) and interest on this Bond at the times, places and rates, and in the coin or currency, herein prescribed.

The Bond is transferable by the registered Holder hereof in person or by attorney upon surrender  hereof  at  the  office  or  agency  of  the  Company in the Borough of Manhattan, New York, New York, together with a written instrument of transfer in approved form, signed by the Holder, and a new Bond or Bonds of this series for a like principal amount in authorized denominations  will  be  issued  in exchange, all  as  provided in  the Indenture.   Prior to due presentment for registration  of  transfer of  this  bond  the  Company and the Trustee may deem and treat  the  registered  owner  hereof  as  the  absolute  owner  hereof, whether or not this bond be overdue,  for  the  purpose  of  receiving  payment  and  for  all other purposes, and neither the Company nor the Trustee shall be affected by any notice to the contrary.  

The Bond is exchangeable at the option of the registered Holder hereof upon surrender hereof,  at  the  office  or  agency  of  the  Company in the Borough of Manhattan, New York, New York, for an equal principal amount of Bonds of this series of other authorized denominations, in the manner and on the terms provided in the Indenture.   

No  service  charge  shall  be made  for  any transfer or exchange hereinbefore referred to, but the  Company  may  require  payment  of  a  sum sufficient to cover any tax or other governmental charge payable in connection therewith.

The  Company,  the  Trustee  and  any  agent  of  the  Company or the Trustee may treat the Person in whose name this Bond is registered as the owner hereof for the purpose of receiving payment as herein provided and for all other purposes, whether or not this Bond is overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

As set forth in the Supplemental Indenture establishing the terms and series of the bonds of this series, each  holder of  a Series  M  Bond, solely by virtue of its acquisition thereof, including as an owner of  a  book-entry  interest therein, has  and  has been deemed to have consented, without the

A-5

need  for  any  further  action  or  consent by such holder, to the amendment and restatement of the Indenture  in  the  form  set  forth  in Exhibit B to the 11th Supplemental Indenture dated as of January 1, 2014.

Unless the certificate of authentication hereon has been executed by the Trustee or Authenticating Agent by manual signature, this Bond shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

A-6

IN WITNESS WHEREOF, the Company has caused this Bond to be duly executed under its corporate seal.

Dated: __________________

YANKEE GAS SERVICES COMPANY

doing business as EVERSOURCE ENERGY

By:                                              

Philip J. Lembo

Vice President and Treasurer  

Attest:

[Signature page for Yankee Gas Services Company, First Mortgage Bond, 3.35% Series M, Due 2025]

A-7

This is one of the Bonds of the series designated therein referred to in the within-mentioned Indenture.

THE BANK OF NEW YORK MELLON

TRUST COMPANY, N.A., as Trustee

Dated: __________________

By:                                                           

Authorized Officer

[Authentication page for Yankee Gas Services Company, First Mortgage Bond, 3.35% Series M, Due 2025]

A-8

EX-12

Converted by EDGARwiz

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Thomas J. May, 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:  November 6, 2015

/s/	Thomas J. May
	Thomas J. May
	Chairman, 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, 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:  November 6, 2015

/s/	James J. Judge
	James J. Judge
	Executive Vice President and Chief Financial Officer
	(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 September 30, 2015 as filed with the Securities and Exchange Commission (the Report), we, Thomas J. May, Chairman, President and Chief Executive Officer of the registrant, and James J. Judge, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

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

2)

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

/s/	Thomas J. May
	Thomas J. May
	Chairman, President and Chief Executive Officer

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

Date:  November 6, 2015

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)
		Nine Months
		Ended
		September 30,		For the Years Ended December 31,
(Thousands of Dollars)		2015		2014		2013		2012		2011		2010
Earnings, as defined:
	Net income	$	228,192	$	287,754	$	279,412	$	209,725	$	250,164	$	244,143
	Income tax expense		127,845		133,451		141,663		94,437		90,033		132,438
	Equity in earnings of regional nuclear  generating companies		(22)		(32)		(67)		(40)		(16)		(134)
	Dividends received from regional equity investees		-		-		289		-		-		440
	Fixed charges, as below		113,620		152,513		139,929		139,982		140,311		145,297
	Less: Interest capitalized (including AFUDC)		(1,738)		(1,867)		(2,249)		(2,456)		(3,317)		(2,726)
Total earnings, as defined		$	467,897	$	571,819	$	558,977	$	441,648	$	477,175	$	519,458
Fixed charges, as defined:
	Interest Expense	$	109,463	$	147,421	$	133,650	$	133,127	$	132,727	$	137,738
	Rental interest factor		2,419		3,225		4,030		4,399		4,267		4,833
	Interest capitalized (including AFUDC)		1,738		1,867		2,249		2,456		3,317		2,726
Total fixed charges, as defined		$	113,620	$	152,513	$	139,929	$	139,982	$	140,311	$	145,297
Ratio of Earnings to Fixed Charges			4.12		3.75		3.99		3.16		3.40		3.58

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Thomas J. May, 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:  November 6, 2015

/s/	Thomas J. May
	Thomas J. May
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

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:  November 6, 2015

/s/	James J. Judge
	James J. Judge
	Executive Vice President and Chief Financial Officer
	(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 September 30, 2015 as filed with the Securities and Exchange Commission (the Report), we, Thomas J. May, Chairman of the registrant, and James J. Judge, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

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

2)

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

/s/	Thomas J. May
	Thomas J. May
	Chairman

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

Date:  November 6, 2015

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)
		Nine Months
		Ended
		September 30,		For the Years Ended December 31,
(Thousands of Dollars)		2015		2014		2013		2012		2011		2010
Earnings, as defined:
	Net income	$	284,148	$	303,088	$	268,546	$	190,242	$	252,494	$	248,575
	Income tax expense		187,397		201,981		172,866		123,966		165,686		162,020
	Equity in earnings of regional nuclear    generating and transmission companies		(326)		(408)		(550)		(412)		(501)		(836)
	Dividends received from regional equity investees		-		-		344		286		676		669
	Fixed charges, as below		60,633		82,503		73,115		72,364		76,219		77,902
	Less: Interest capitalized (including AFUDC)		(1,466)		(2,027)		(511)		(259)		(185)		(108)
Total earnings, as defined		$	530,386	$	585,137	$	513,810	$	386,187	$	494,389	$	488,222
Fixed charges, as defined:
	Interest Expense	$	57,218	$	77,878	$	70,383	$	70,054	$	69,427	$	71,390
	Rental interest factor		1,949		2,598		2,221		2,051		6,607		6,404
	Interest capitalized (including AFUDC)		1,466		2,027		511		259		185		108
Total fixed charges, as defined		$	60,633	$	82,503	$	73,115	$	72,364	$	76,219	$	77,902
Ratio of Earnings to Fixed Charges			8.75		7.09		7.03		5.34		6.49		6.27

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Thomas J. May, 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:  November 6, 2015

/s/	Thomas J. May
	Thomas J. May
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

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:  November 6, 2015

/s/	James J. Judge
	James J. Judge
	Executive Vice President and Chief Financial Officer
	(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 September 30, 2015 as filed with the Securities and Exchange Commission (the Report), we, Thomas J. May, Chairman of the registrant, and James J. Judge, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

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

2)

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

/s/	Thomas J. May
	Thomas J. May
	Chairman

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

Date:  November 6, 2015

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)
		Nine Months
		Ended
		September 30,		For the Years Ended December 31,
(Thousands of Dollars)		2015			2014		2013		2012		2011		2010
Earnings, as defined:
	Net income	$	92,491	$	113,944	$	111,397	$	96,882	$	100,267	$	90,067
	Income tax expense		56,135		72,135		71,101		60,993		49,945		50,801
	Equity in earnings of regional nuclear   generating companies		(5)		(8)		(12)		(8)		(7)		(23)
	Dividends received from regional equity investees		-		-		42		-		-		80
	Fixed charges, as below		35,624		46,530		47,318		52,769		52,111		54,721
	Less: Interest capitalized (including AFUDC)		(636)		(640)		(500)		(1,579)		(7,064)		(6,621)
Total earnings, as defined		$	183,609	$	231,961	$	229,346	$	209,057	$	195,252	$	189,025
Fixed charges, as defined:
	Interest Expense	$	34,582	$	45,349	$	46,176	$	50,228	$	44,147	$	47,067
	Rental interest factor		406		541		642		962		900		1,033
	Interest capitalized (including AFUDC)		636		640		500		1,579		7,064		6,621
Total fixed charges, as defined		$	35,624	$	46,530	$	47,318	$	52,769	$	52,111	$	54,721
Ratio of Earnings to Fixed Charges			5.15		4.99		4.85		3.96		3.75		3.45

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Thomas J. May, 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:  November 6, 2015

/s/	Thomas J. May
	Thomas J. May
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

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:  November 6, 2015

/s/	James J. Judge
	James J. Judge
	Executive Vice President and Chief Financial Officer
	(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 September 30, 2015 as filed with the Securities and Exchange Commission (the Report), we, Thomas J. May, Chairman of the registrant, and James J. Judge, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

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

2)

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

/s/	Thomas J. May
	Thomas J. May
	Chairman

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

Date:  November 6, 2015

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)
		Nine Months
		Ended
		September 30,		For the Years Ended December 31,
(Thousands of Dollars)		2015		2014		2013		2012		2011		2010
Earnings, as defined:
	Net income	$	42,410	$	57,819	$	60,438	$	54,503	$	43,054	$	23,090
	Income tax expense		28,555		37,268		37,368		32,140		23,186		16,325
	Equity in earnings of regional nuclear   generating companies		(6)		(8)		(18)		(11)		(4)		(36)
	Dividends received from regional equity investees		-		-		80		-		-		120
	Fixed charges, as below		20,125		26,202		26,316		28,162		25,079		23,042
	Less: Interest capitalized (including AFUDC)		(806)		(864)		(498)		(534)		(534)		(336)
Total earnings, as defined		$	90,278	$	120,417	$	123,686	$	114,260	$	90,781	$	62,205
Fixed charges, as defined:
	Interest Expense	$	19,014	$	24,931	$	24,851	$	26,634	$	23,612	$	21,839
	Rental interest factor		305		407		967		994		933		867
	Interest capitalized (including AFUDC)		806		864		498		534		534		336
Total fixed charges, as defined		$	20,125	$	26,202	$	26,316	$	28,162	$	25,079	$	23,042
Ratio of Earnings to Fixed Charges			4.49		4.60		4.70		4.06		3.62		2.70

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Thomas J. May, 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:  November 6, 2015

/s/	Thomas J. May
	Thomas J. May
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

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:  November 6, 2015

/s/	James J. Judge
	James J. Judge
	Executive Vice President and Chief Financial Officer
	(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 September 30, 2015 as filed with the Securities and Exchange Commission (the Report), we, Thomas J. May, Chairman of the registrant, and James J. Judge, Executive Vice President and Chief Financial Officer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

1)

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

2)

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

/s/	Thomas J. May
	Thomas J. May
	Chairman

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

Date:  November 6, 2015

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.

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Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Capital Expenditures Incurred But Not Yet Paid	$ 160.7	$ 128.9
The Connecticut Light And Power Company [Member]
Capital Expenditures Incurred But Not Yet Paid	46.0	52.2
NSTAR Electric Company [Member]
Capital Expenditures Incurred But Not Yet Paid	31.2	18.1
Public Service Company Of New Hampshire [Member]
Capital Expenditures Incurred But Not Yet Paid	33.8	21.0
Western Massachusetts Electric Company [Member]
Capital Expenditures Incurred But Not Yet Paid	$ 15.5	$ 10.0

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COMMON SHARES (Details) - $ / shares	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
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	333,862,615	333,359,172
Treasury Stock Shares	16,671,366	16,375,835
Common Stock, Shares, Outstanding	317,191,249	316,983,337
Treasury Stock Shares Acquired	532,521
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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INCOME TAXES (Details)	3 Months Ended
	Sep. 30, 2015
Other Tax Disclosures [Abstract]
Other Information Pertaining To Income Taxes	Part of the annual process in making adjustments to these estimates is reconciling the provision for income taxes made during the income tax estimation process to what was filed in the income tax return (return to provision). In the third quarter of 2015, Eversource and CL&P recorded an $8 million and $4.2 million charge, respectively, as a result of reconciling and adjusting its 2014 provision for income taxes to what was filed on its 2014 income tax return. Concurrently, Eversource and CL&P recorded a reversal of state tax reserves in the third quarter of 2015, which resulted in a $5.9 million and $2.2 million benefit, respectively.
The Connecticut Light And Power Company [Member]
Other Tax Disclosures [Abstract]
Other Information Pertaining To Income Taxes	Part of the annual process in making adjustments to these estimates is reconciling the provision for income taxes made during the income tax estimation process to what was filed in the income tax return (return to provision). In the third quarter of 2015, Eversource and CL&P recorded an $8 million and $4.2 million charge, respectively, as a result of reconciling and adjusting its 2014 provision for income taxes to what was filed on its 2014 income tax return. Concurrently, Eversource and CL&P recorded a reversal of state tax reserves in the third quarter of 2015, which resulted in a $5.9 million and $2.2 million benefit, respectively.

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SHORT AND LONG-TERM TERM DEBT (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Line of Credit Facility, Description	Credit Agreements and Commercial Paper Programs: On October 26, 2015, Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas amended and restated their joint five-year $1.45 billion revolving credit facility and extended the termination date to September 4, 2020. The facility serves to backstop Eversource parent's $1.45 billion commercial paper program. The commercial paper program allows Eversource parent to issue commercial paper as a form of short-term debt. As of September 30, 2015 and December 31, 2014, Eversource parent had $757 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $693 million and $348.9 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively. The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.41 percent and 0.43 percent, respectively. As of September 30, 2015, there were intercompany loans from Eversource parent of $137.3 million to PSNH and $126.2 million to WMECO. As of December 31, 2014, there were intercompany loans from Eversource parent of $133.4 million to CL&P, $90.5 million to PSNH and $21.4 million to WMECO. On October 26, 2015, NSTAR Electric amended and restated its five-year $450 million revolving credit facility and extended the termination date to September 4, 2020. The facility serves to backstop NSTAR Electric's $450 million commercial paper program. As of September 30, 2015 and December 31, 2014, NSTAR Electric had $258.5 million and $302 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $191.5 million and $148 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively. The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.18 percent and 0.27 percent, respectively.
Notes Payable	$ 1,015,500	$ 956,825
Long-term Debt, Description	Long-Term Debt: On January 15, 2015, Eversource parent issued $150 million of 1.60 percent Series G Senior Notes, due to mature in 2018 and $300 million of 3.15 percent Series H Senior Notes, due to mature in 2025. The proceeds, net of issuance costs, were used to repay short-term borrowings outstanding under the Eversource parent commercial paper program. As the debt issuances refinanced short-term debt, the short-term debt was classified as Long-Term Debt as of December 31, 2014. On April 1, 2015, CL&P repaid at maturity the $100 million 5.00 percent 2005 Series A First and Refunding Mortgage Bonds using short-term borrowings. On April 1, 2015, CL&P also redeemed the $62 million 1996A Series 1.55 percent PCRBs that were subject to mandatory tender, using short term borrowings. On May 20, 2015, CL&P issued $300 million of 4.15 percent 2015 Series A First and Refunding Mortgage Bonds due to mature in 2045. The proceeds, net of issuance costs, were used to repay short-term borrowings. On August 3, 2015, WMECO repaid at maturity the $50 million 5.24 percent Series C Senior Notes using short-term borrowings. On September 10, 2015, Yankee Gas issued $75 million of 3.35 percent 2015 Series M First Mortgage Bonds due to mature in 2025. The proceeds, net of issuance costs, were used to repay short-term borrowings.
The Connecticut Light And Power Company [Member]
Line of Credit Facility [Line Items]
Notes Payable To Affiliated Companies	$ 0	133,400
Long-term Debt, Description	On April 1, 2015, CL&P repaid at maturity the $100 million 5.00 percent 2005 Series A First and Refunding Mortgage Bonds using short-term borrowings. On April 1, 2015, CL&P also redeemed the $62 million 1996A Series 1.55 percent PCRBs that were subject to mandatory tender, using short term borrowings. On May 20, 2015, CL&P issued $300 million of 4.15 percent 2015 Series A First and Refunding Mortgage Bonds due to mature in 2045. The proceeds, net of issuance costs, were used to repay short-term borrowings.
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	$ 191,500	$ 148,000
Short-term Debt, Weighted Average Interest Rate	0.18%	0.27%
CommercialPaper	$ 258,500	$ 302,000
Notes Payable	258,500	302,000
Public Service Company Of New Hampshire [Member]
Line of Credit Facility [Line Items]
Notes Payable To Affiliated Companies	137,300	90,500
Western Massachusetts Electric Company [Member]
Line of Credit Facility [Line Items]
Notes Payable To Affiliated Companies	$ 126,200	21,400
Long-term Debt, Description	On August 3, 2015, WMECO repaid at maturity the $50 million 5.24 percent Series C Senior Notes using short-term borrowings.
Eversource Parent [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,450,000
Line of Credit Facility, Remaining Borrowing Capacity	$ 693,000	$ 348,900
Short-term Debt, Weighted Average Interest Rate	0.41%	0.43%
CommercialPaper	$ 757,000	$ 1,100,000

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COMMON SHARES (Tables)

3 Months Ended

Sep. 30, 2015

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 and the respective per share par values:

	Shares
			Authorized as of
	Per Share		September 30, 2015 and	Issued as of
	Par Value		December 31, 2014	September 30, 2015	December 31, 2014
Eversource	$	5	380,000,000	333,862,615	333,359,172
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 September 30, 2015 and December31, 2014, there were 16,671,366 and 16,375,835 Eversource common shares held as treasury shares, respectively. As of September 30, 2015 and December31, 2014, Eversource common shares outstanding were 317,191,249 and 316,983,337, respectively. In May 2015, the Company repurchased 532,521 treasury shares at a share price of $47.94.

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PROPERTY, PLANT AND ACCUMULATED DEPRECIATION (Tables)

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

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

		As of September 30, 2015		As of December 31, 2014
(Millions of Dollars)		Eversource		Eversource
Distribution - Electric		$	12,821.6	$	12,495.2
Distribution - Natural Gas			2,657.5		2,595.4
Transmission			7,260.6		6,930.7
Generation			1,180.0		1,170.9
Electric and Natural Gas Utility			23,919.7		23,192.2
Other (1)			555.3		551.3
Property, Plant and Equipment, Gross			24,475.0		23,743.5
Less: Accumulated Depreciation
	Electric and Natural Gas Utility		(6,041.5)		(5,777.8)
	Other		(247.6)		(231.8)
Total Accumulated Depreciation			(6,289.1)		(6,009.6)
Property, Plant and Equipment, Net			18,185.9		17,733.9
Construction Work in Progress			1,220.1		913.1
Total Property, Plant and Equipment, Net		$	19,406.0	$	18,647.0

	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Distribution	$	5,289.6	$	5,001.9	$	1,772.0	$	798.1	$	5,158.8	$	4,895.5	$	1,696.7	$	784.2
Transmission		3,480.5		1,995.3		839.9		896.7		3,274.0		1,928.5		789.7		891.0
Generation		-		-		1,145.5		34.5		-		-		1,136.5		34.4
Property, Plant and Equipment, Gross		8,770.1		6,997.2		3,757.4		1,729.3		8,432.8		6,824.0		3,622.9		1,709.6
Less: Accumulated Depreciation		(2,007.9)		(1,857.9)		(1,149.6)		(302.6)		(1,928.0)		(1,761.4)		(1,090.0)		(297.4)
Property, Plant and Equipment, Net		6,762.2		5,139.3		2,607.8		1,426.7		6,504.8		5,062.6		2,532.9		1,412.2
Construction Work in Progress		246.4		405.8		160.4		105.0		304.9		272.8		102.9		49.1
Total Property, Plant and Equipment, Net	$	7,008.6	$	5,545.1	$	2,768.2	$	1,531.7	$	6,809.7	$	5,335.4	$	2,635.8	$	1,461.3

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Guarantees and Indemnifications (Details)	Sep. 30, 2015 USD ($)
Guarantee Of Financial Obligations Of Npt [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	$ 25,000,000
Various Subsidiary Surety Bonds And Performance Guarantees Expiring Between 2015 And 2016 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	33,200,000
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	12,200,000
Guarantee To Purchaser Of Es Boulos Company And A Bonding Company Expiring In 2016 And 2020 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	38,200,000
Access Northeast Project Capital Contributions Guarantee Expiring In 2021 [Member]
Guarantee Obligations [Line Items]
Guarantee Obligations Maximum Exposure	$ 206.0

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PROPERTY, PLANT AND ACCUMULATED DEPRECIATION (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	$ 12,821,600	$ 12,495,200
Public Utilities Property Plant And Equipment Distribution Natural Gas	2,657,500	2,595,400
Public Utilities Property Plant And Equipment Transmission	7,260,600	6,930,700
Public Utilities Property Plant And Equipment Generation Or Processing	1,180,000	1,170,900
Public Utilities Property Plant And Equipment Electric And Natural Gas Utility Total	23,919,700	23,192,200
Public Utilities Property Plant And Equipment Other Property Plant And Equipment	555,300	551,300
Public Utilities Property Plant And Equipment Plant In Service	24,475,000	23,743,500
Less Accumulated Depreciation [Abstract]
Electric And Natural Gas Utility Accumulated Depreciation	(6,041,500)	(5,777,800)
Other Accumulated Depreciation	(247,600)	(231,800)
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(6,289,100)	(6,009,600)
Property Plant And Equipment Net Excluding Construction Work In Progress	18,185,900	17,733,900
Public Utilities Property Plant And Equipment Construction Work In Progress	1,220,100	913,100
Property, Plant and Equipment, Net	19,406,025	18,647,041
The Connecticut Light And Power Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	5,289,600	5,158,800
Public Utilities Property Plant And Equipment Transmission	3,480,500	3,274,000
Public Utilities Property Plant And Equipment Generation Or Processing	0	0
Public Utilities Property Plant And Equipment Plant In Service	8,770,100	8,432,800
Less Accumulated Depreciation [Abstract]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(2,007,900)	(1,928,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	6,762,200	6,504,800
Public Utilities Property Plant And Equipment Construction Work In Progress	246,400	304,900
Property, Plant and Equipment, Net	7,008,603	6,809,664
NSTAR Electric Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	5,001,900	4,895,500
Public Utilities Property Plant And Equipment Transmission	1,995,300	1,928,500
Public Utilities Property Plant And Equipment Generation Or Processing	0	0
Public Utilities Property Plant And Equipment Plant In Service	6,997,200	6,824,000
Less Accumulated Depreciation [Abstract]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,857,900)	(1,761,400)
Property Plant And Equipment Net Excluding Construction Work In Progress	5,139,300	5,062,600
Public Utilities Property Plant And Equipment Construction Work In Progress	405,800	272,800
Property, Plant and Equipment, Net	5,545,082	5,335,436
Public Service Company Of New Hampshire [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	1,772,000	1,696,700
Public Utilities Property Plant And Equipment Transmission	839,900	789,700
Public Utilities Property Plant And Equipment Generation Or Processing	1,145,500	1,136,500
Public Utilities Property Plant And Equipment Plant In Service	3,757,400	3,622,900
Less Accumulated Depreciation [Abstract]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(1,149,600)	(1,090,000)
Property Plant And Equipment Net Excluding Construction Work In Progress	2,607,800	2,532,900
Public Utilities Property Plant And Equipment Construction Work In Progress	160,400	102,900
Property, Plant and Equipment, Net	2,768,206	2,635,844
Public Service Company Of New Hampshire [Member] | Generation Plant [Member]
Less Accumulated Depreciation [Abstract]
Electric And Natural Gas Utility Accumulated Depreciation	(514,000)
Western Massachusetts Electric Company [Member]
Public Utility Property Plant And Equipment [Line Items]
Public Utilities Property Plant And Equipment Distribution	798,100	784,200
Public Utilities Property Plant And Equipment Transmission	896,700	891,000
Public Utilities Property Plant And Equipment Generation Or Processing	34,500	34,400
Public Utilities Property Plant And Equipment Plant In Service	1,729,300	1,709,600
Less Accumulated Depreciation [Abstract]
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation	(302,600)	(297,400)
Property Plant And Equipment Net Excluding Construction Work In Progress	1,426,700	1,412,200
Public Utilities Property Plant And Equipment Construction Work In Progress	105,000	49,100
Property, Plant and Equipment, Net	$ 1,531,705	$ 1,461,321

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Provision for Uncollectible Accounts (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	$ 185.8	$ 175.3
Uncollectible Hardship Accounts Receivable Reserve	86.6	91.5
The Connecticut Light And Power Company [Member]
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	79.5	84.3
Uncollectible Hardship Accounts Receivable Reserve	64.9	74.0
NSTAR Electric Company [Member]
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	46.4	40.7
Public Service Company Of New Hampshire [Member]
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	9.4	7.7
Western Massachusetts Electric Company [Member]
Accounts Notes And Loans Receivable [Line Items]
Allowance For Doubtful Accounts Receivable Current	13.2	9.9
Uncollectible Hardship Accounts Receivable Reserve	$ 7.7	$ 6.2

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
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	8,986,400	8,851,600
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	157,300	153,600
Other Long Term Debt	9,419,600	9,451,200
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	2,975,300	2,842,000
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	115,400	112,000
Other Long Term Debt	3,285,100	3,214,500
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	1,792,700	1,797,400
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	41,900	41,600
Other Long Term Debt	1,931,300	1,993,500
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	1,076,300	1,076,300
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	1,135,500	1,137,900
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	577,800	628,500
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	$ 613,300	$ 689,400

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PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	$ 1,498,346		$ 1,498,346		$ 1,638,558
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Amount That Represents Deferred Regulatory Assets	800		2,400
Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	22,700	$ 19,100	68,700	$ 60,700
Defined Benefit Plan Interest Cost	56,900	56,400	170,300	169,500
Defined Benefit Plan, Expected Return on Plan Assets	(83,900)	(77,700)	(252,100)	(233,100)
Defined Benefit Plan, Amortization of Gains (Losses)	36,500	31,700	111,900	96,500
Defined Benefit Plan Amortization Of Prior Service Cost Credit	900	1,100	2,700	3,300
Defined Benefit Plan Net Periodic Benefit Cost	33,100	30,600	101,500	96,900
Amount Capitalized Defined Benefit Expense	9,800	8,300	31,300	26,700
PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	4,100	3,100	10,300	9,300
Defined Benefit Plan Interest Cost	11,800	12,400	30,400	37,100
Defined Benefit Plan, Expected Return on Plan Assets	(16,900)	(15,800)	(43,200)	(47,400)
Defined Benefit Plan, Amortization of Gains (Losses)	1,700	3,000	4,500	9,100
Defined Benefit Plan Amortization Of Prior Service Cost Credit	(100)	(700)	(300)	(2,100)
Defined Benefit Plan Net Periodic Benefit Cost	600	2,000	1,700	6,000
Amount Capitalized Defined Benefit Expense	0	1,100	100	1,900
The Connecticut Light And Power Company [Member]
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	284,890		284,890		273,854
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	6,200	5,000	18,400	15,200
Defined Benefit Plan Interest Cost	12,900	12,500	38,400	38,100
Defined Benefit Plan, Expected Return on Plan Assets	(19,800)	(18,700)	(59,100)	(56,700)
Defined Benefit Plan, Amortization of Gains (Losses)	8,000	8,200	24,200	25,500
Defined Benefit Plan Amortization Of Prior Service Cost Credit	400	400	1,100	1,400
Defined Benefit Plan Net Periodic Benefit Cost	7,700	7,400	23,000	23,500
Related Intercompany Allocationsof Defined Benefit Expense	5,800	6,500	18,000	20,800
Amount Capitalized Defined Benefit Expense	4,700	4,300	14,100	13,600
The Connecticut Light And Power Company [Member] | PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	500	600	1,600	1,700
Defined Benefit Plan Interest Cost	1,800	2,000	5,400	6,000
Defined Benefit Plan, Expected Return on Plan Assets	(2,800)	(2,600)	(8,300)	(7,900)
Defined Benefit Plan, Amortization of Gains (Losses)	200	1,000	500	3,200
Defined Benefit Plan Amortization Of Prior Service Cost Credit			0	0
Defined Benefit Plan Net Periodic Benefit Cost	(300)	1,000	(800)	3,000
Related Intercompany Allocationsof Defined Benefit Expense	400	900	1,400	3,100
Amount Capitalized Defined Benefit Expense	(100)	500	(200)	1,500
NSTAR Electric Company [Member]
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	211,891		211,891		235,529
NSTAR Electric Company [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	3,700	3,000	11,200	10,600
Defined Benefit Plan Interest Cost	10,000	10,300	30,200	31,000
Defined Benefit Plan, Expected Return on Plan Assets	(17,500)	(15,700)	(52,500)	(47,300)
Defined Benefit Plan, Amortization of Gains (Losses)	8,700	5,900	27,000	17,600
Defined Benefit Plan Amortization Of Prior Service Cost Credit	0	0	100	0
Defined Benefit Plan Net Periodic Benefit Cost	4,900	3,500	16,000	11,900
Related Intercompany Allocationsof Defined Benefit Expense	3,400	2,900	10,300	6,700
Amount Capitalized Defined Benefit Expense	2,700	2,600	8,600	5,500
NSTAR Electric Company [Member] | PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	1,300	800	4,000	2,300
Defined Benefit Plan Interest Cost	4,800	4,900	14,200	14,600
Defined Benefit Plan, Expected Return on Plan Assets	(6,800)	(6,500)	(20,500)	(19,500)
Defined Benefit Plan, Amortization of Gains (Losses)	600	(100)	1,800	(400)
Defined Benefit Plan Amortization Of Prior Service Cost Credit	(100)	(500)	(100)	(1,400)
Defined Benefit Plan Net Periodic Benefit Cost	(200)	(1,400)	(600)	(4,400)
Related Intercompany Allocationsof Defined Benefit Expense	200	300	700	400
Amount Capitalized Defined Benefit Expense	0	(500)	(100)	(1,500)
Public Service Company Of New Hampshire [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Amortization Of Prior Service Cost Credit		0
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	97,167		97,167		93,243
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	3,100	2,300	9,000	7,400
Defined Benefit Plan Interest Cost	6,100	5,700	18,100	18,000
Defined Benefit Plan, Expected Return on Plan Assets	(10,100)	(9,300)	(30,300)	(28,800)
Defined Benefit Plan, Amortization of Gains (Losses)	2,900	2,800	8,800	8,900
Defined Benefit Plan Amortization Of Prior Service Cost Credit	100	100	400	500
Defined Benefit Plan Net Periodic Benefit Cost	2,100	1,600	6,000	6,000
Related Intercompany Allocationsof Defined Benefit Expense	1,600	1,800	5,000	6,000
Amount Capitalized Defined Benefit Expense	800	700	2,600	2,400
Public Service Company Of New Hampshire [Member] | PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	300	300	1,000	1,000
Defined Benefit Plan Interest Cost	1,000	1,100	2,900	3,200
Defined Benefit Plan, Expected Return on Plan Assets	(1,500)	(1,400)	(4,400)	(4,100)
Defined Benefit Plan, Amortization of Gains (Losses)	100	600	400	1,700
Defined Benefit Plan Amortization Of Prior Service Cost Credit			0	0
Defined Benefit Plan Net Periodic Benefit Cost	(100)	600	(100)	1,800
Related Intercompany Allocationsof Defined Benefit Expense	100	200	300	800
Amount Capitalized Defined Benefit Expense	100	200	200	600
Western Massachusetts Electric Company [Member]
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract]
Accrued Pension, SERP and PBOP	18,320		18,320		$ 17,705
Western Massachusetts Electric Company [Member] | Pension Plans Defined Benefit Member
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	1,000	800	3,200	2,700
Defined Benefit Plan Interest Cost	2,600	2,500	7,800	7,800
Defined Benefit Plan, Expected Return on Plan Assets	(4,700)	(4,400)	(14,200)	(13,500)
Defined Benefit Plan, Amortization of Gains (Losses)	1,600	1,700	4,800	5,200
Defined Benefit Plan Amortization Of Prior Service Cost Credit	100	100	200	300
Defined Benefit Plan Net Periodic Benefit Cost	600	700	1,800	2,500
Related Intercompany Allocationsof Defined Benefit Expense	1,100	1,200	3,300	3,900
Amount Capitalized Defined Benefit Expense	500	600	1,400	2,000
Western Massachusetts Electric Company [Member] | PBOP Plan
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan Service Cost	100	100	300	300
Defined Benefit Plan Interest Cost	300	400	1,100	1,300
Defined Benefit Plan, Expected Return on Plan Assets	(600)	(600)	(1,900)	(1,700)
Defined Benefit Plan, Amortization of Gains (Losses)	0	100	0	300
Defined Benefit Plan Amortization Of Prior Service Cost Credit			0	0
Defined Benefit Plan Net Periodic Benefit Cost	(200)	0	(500)	200
Related Intercompany Allocationsof Defined Benefit Expense	100	200	300	600
Amount Capitalized Defined Benefit Expense	$ 0	$ 0	$ (100)	$ 100

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DERIVATIVE INSTRUMENTS

9 Months Ended

Sep. 30, 2015

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 amount recorded as current or long-term derivative asset or liability:

		As of September 30, 2015						As of December 31, 2014
		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 3:
	Eversource	$	16.6	$	(10.8)	$	5.8	$	16.2	$	(6.6)	$	9.6
	CL&P		16.6		(10.8)		5.8		16.1		(6.6)		9.5
	NSTAR Electric		-		-		-		0.1		-		0.1
Long-Term Derivative Assets:
Level 3:
	Eversource	$	67.7	$	(22.2)	$	45.5	$	93.5	$	(19.2)	$	74.3
	CL&P		65.6		(22.2)		43.4		93.5		(19.2)		74.3
	NSTAR Electric		2.1		-		2.1		-		-		-
Current Derivative Liabilities:
Level 2:
	Eversource	$	(4.6)	$	-	$	(4.6)	$	(9.8)	$	-	$	(9.8)
Level 3:
	Eversource		(92.6)		-		(92.6)		(90.0)		-		(90.0)
	CL&P		(91.4)		-		(91.4)		(88.5)		-		(88.5)
	NSTAR Electric		(1.2)		-		(1.2)		(1.5)		-		(1.5)
Long-Term Derivative Liabilities:
Level 2:
	Eversource	$	-	$	-	$	-	$	(0.3)	$	-	$	(0.3)
Level 3:
	Eversource		(365.7)		-		(365.7)		(409.3)		-		(409.3)
	CL&P		(364.7)		-		(364.7)		(406.2)		-		(406.2)
	NSTAR Electric		(1.0)		-		(1.0)		(3.1)		-		(3.1)

(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 each contract allocated to CL&P and 20 percent allocated to UI. The combined capacity of these contracts is 787 MW. The capacity contracts extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market price received in the ISO-NE capacity markets. In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020.

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

As of September 30, 2015 and December31, 2014, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately 9.9million and 8.8 million MMBtu of natural gas, respectively.

For the three months ended September 30, 2015 and 2014, there were losses of $8.8million and $15.7million, respectively, deferred as regulatory costs, which reflect the current change in fair value associated with Eversource's derivative contracts.For the nine months ended September 30, 2015 and 2014, there were losses of $58.9million and gains of $149.9million, respectively.

Credit Risk

Certain of Eversource's derivative contracts contain credit risk contingent provisions. These provisions require Eversource to maintain investment grade credit ratings from the major rating agencies and to post collateral for contracts in a net liability position over specified credit limits. As of September 30, 2015 and December 31, 2014, Eversource had approximately $4.6million and $10 million, respectively,of derivative contracts in a net liability position that were subject to credit risk contingent provisions and would have been required to post additional collateral of approximately $4.7million and $10 million, respectively, if Eversource parent's unsecured debt credit ratings had been downgraded to below investment grade.

Fair Value Measurements of Derivative Instruments

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

The fair value of derivative contracts classified as Level 3 utilizes significant unobservable inputs. The fair value is modeled using income techniques, such as discounted cash flow valuations adjusted for assumptions relating to exit price. Significant observable inputs for valuations of these contracts include energy and energy-related product prices in future years for which quoted prices in an active market exist. Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy and energy-related products, and accounting requirements. The future power and capacity prices for periods that are not quoted in an active market or established at auction are based on available market data and are escalated based on estimates of inflation 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 September 30, 2015						As of December 31, 2014
		Range				Period Covered		Range				Period Covered
Capacity Prices:
Eversource	$	10.30	-	13.13	per kW-Month	2016 - 2026	$	5.30	-	12.98	per kW-Month	2016 - 2026
CL&P	$	10.81	-	12.60	per kW-Month	2019 - 2026	$	11.08	-	12.98	per kW-Month	2018 - 2026
NSTAR Electric	$	10.30	-	13.13	per kW-Month	2016 - 2019	$	5.30	-	11.10	per kW-Month	2016 - 2019
Forward Reserve:
Eversource, CL&P	$	2.00			per kW-Month	2016 - 2024	$	5.80	-	9.50	per kW-Month	2015 - 2024
REC Prices:
Eversource, NSTAR Electric	$	45	-	50	per REC	2015 - 2018	$	38	-	56	per REC	2015 - 2018

Exit price premiums of 6 percent through 23percent are also applied on these contracts and reflect 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 the risk premiums would increase the fair value of the derivative liabilities. Changes in these fair values are recorded as a regulatory asset or liability and would not impact net income.

Valuations using significant unobservable inputs: The following table presents changes in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis. The derivative assets and liabilities are presented on a net basis.

	For the Three Months Ended September 30,
	2015						2014
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(422.4)	$	(420.2)	$	(2.2)	$	(430.9)	$	(424.6)	$	(6.3)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities		(6.0)		(7.6)		1.6		(13.6)		(15.0)		1.4
Settlements		21.4		20.9		0.5		21.0		18.5		2.5
Fair Value as of End of Period	$	(407.0)	$	(406.9)	$	(0.1)	$	(423.5)	$	(421.1)	$	(2.4)
	For the Nine Months Ended September 30,
	2015						2014
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(415.4)	$	(410.9)	$	(4.5)	$	(635.2)	$	(630.6)	$	(7.3)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities		(55.3)		(56.6)		1.3		147.6		149.4		0.9
Settlements		63.7		60.6		3.1		64.1		60.1		4.0
Fair Value as of End of Period	$	(407.0)	$	(406.9)	$	(0.1)	$	(423.5)	$	(421.1)	$	(2.4)

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DERIVATIVE INSTURMENTS (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015 USD ($) $ / KWmo	Sep. 30, 2014 USD ($)	Sep. 30, 2015 USD ($) $ / KWmo	Sep. 30, 2014 USD ($)	Dec. 31, 2014 USD ($) $ / KWmo $ / REC
Derivative Instrument Detail Abstract
Derivative Liabilities, Noncurrent	$ (365,692)		$ (365,692)		$ (409,632)
Other Derivatives Not Designated As Hedging Instruments At Fair Value Net Total Abstract
Description of Derivative Activity Volume			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 each contract allocated to CL&P and 20 percent allocated to UI. The combined capacity of these contracts is 787 MW. The capacity contracts extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market price received in the ISO-NE capacity markets. In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020. NSTAR Electric has a renewable energy contract to purchase 0.1 million MWh of energy per year through 2018 and a capacity-related contract to purchase up to 35 MW per year through 2019. As of September 30, 2015 and December 31, 2014, Eversource had NYMEX financial contracts for natural gas futures in order to reduce variability associated with the purchase price of approximately 9.9 million and 8.8 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	(8,800)	$ (15,700)	$ (58,900)	$ 149,900
Derivative Credit Risk Related Contingent Features Abstract
Derivative Net Liability Position Aggregate Fair Value	(4,600)		(4,600)		(10,000)
Additional Collateral Aggregate Fair Value	4,700		$ 4,700		10,000
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsExitPricePremium			Exit price premiums of 6 percent through 23 percent are also applied on these contracts and reflect the most recent market activity available for similar type contracts
The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(91,372)		$ (91,372)		(88,459)
Derivative Liabilities, Noncurrent	$ (364,691)		$ (364,691)		(406,199)
Other Derivatives Not Designated As Hedging Instruments At Fair Value Net Total Abstract
Description of Derivative Activity Volume			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 each contract allocated to CL&P and 20 percent 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 Company [Member]
Other Derivatives Not Designated As Hedging Instruments At Fair Value Net Total Abstract
Description of Derivative Activity Volume	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.
Fair Value Inputs Level 2 [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	$ (4,600)		$ (4,600)		(9,800)
Derivative Liabilities, Noncurrent	0		0		(300)
Fair Value Inputs Level 3 [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	5,800		5,800		9,600
Derivative Liabilities - Current	(92,600)		(92,600)		(90,000)
Derivative Liabilities, Noncurrent	(365,700)		(365,700)		(409,300)
Derivative Assets Noncurrent	$ 45,500		$ 45,500		$ 74,300
Fair Value Inputs Level 3 [Member] | Minimum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	10.30		10.30		5.30
FairValueInputsRenewableEnergyCreditPrices | $ / KWmo	45		45		38
FairValueInputsForwardReserve | $ / KWmo	2.00		2.00		5.80
Fair Value Inputs Level 3 [Member] | Maximum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	13.13		13.13		12.98
FairValueInputsRenewableEnergyCreditPrices	50		50		56
FairValueInputsForwardReserve | $ / KWmo					9.50
Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	$ 5,800		$ 5,800		$ 9,500
Derivative Liabilities - Current	(91,400)		(91,400)		(88,500)
Derivative Liabilities, Noncurrent	(364,700)		(364,700)		(406,200)
Derivative Assets Noncurrent	$ 43,400		$ 43,400		$ 74,300
Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member] | Minimum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	10.81		10.81		11.08
FairValueInputsForwardReserve | $ / KWmo	2.00		2.00		5.80
Fair Value Inputs Level 3 [Member] | The Connecticut Light And Power Company [Member] | Maximum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	12.60		12.60		12.98
FairValueInputsForwardReserve | $ / KWmo					9.50
Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current					$ 100
Derivative Liabilities - Current	$ (1,200)		$ (1,200)		(1,500)
Derivative Liabilities, Noncurrent	(1,000)		(1,000)		$ (3,100)
Derivative Assets Noncurrent	$ 2,100		$ 2,100
Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member] | Minimum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	10.30		10.30		5.30
FairValueInputsRenewableEnergyCreditPrices	45		45		38
Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member] | Maximum [Member]
FairValueInputsQuantitativeInformation[Abstract]
FairValueInputsCapacityPrices | $ / KWmo	13.13		13.13		11.10
FairValueInputsRenewableEnergyCreditPrices	50		50		56
Amount Offset Against Derivatives [Member] | Fair Value Inputs Level 2 [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)		$ (6,600)
Derivative Liabilities - Current	0		0
Derivative Assets Noncurrent	(22,200)		(22,200)		(19,200)
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)		(6,600)
Derivative Assets Noncurrent	(22,200)		(22,200)		(19,200)
Commodity [Member] | Fair Value Inputs Level 2 [Member]
Derivative Instrument Detail Abstract
Derivative Liabilities - Current	(4,600)		(4,600)		(9,800)
Derivative Liabilities, Noncurrent	0		0		(300)
Commodity [Member] | Fair Value Inputs Level 3 [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current	16,600		16,600		16,200
Derivative Liabilities - Current	(92,600)		(92,600)		(90,000)
Derivative Liabilities, Noncurrent	(365,700)		(365,700)		(409,300)
Derivative Assets Noncurrent	67,700		67,700		93,500
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		16,100
Derivative Liabilities - Current	(91,400)		(91,400)		(88,500)
Derivative Liabilities, Noncurrent	(364,700)		(364,700)		(406,200)
Derivative Assets Noncurrent	65,600		65,600		93,500
Commodity [Member] | Fair Value Inputs Level 3 [Member] | NSTAR Electric Company [Member]
Derivative Instrument Detail Abstract
Derivative Assets - Current					100
Derivative Liabilities - Current	(1,200)		(1,200)		(1,500)
Derivative Liabilities, Noncurrent	(1,000)		(1,000)		$ (3,100)
Derivative Assets Noncurrent	$ 2,100		$ 2,100

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Environmental Matters (Tables)

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Environmental Loss Contingencies By Site Text Block

	As of September 30, 2015				As of December 31, 2014
			Reserve				Reserve
	Number of Sites		(in millions)		Number of Sites		(in millions)
Eversource		64	$	46.9		65	$	43.3
CL&P		14		4.8		16		3.8
NSTAR Electric		14		2.2		13		1.1
PSNH		12		3.4		13		5.2
WMECO		4		0.6		4		0.5

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Pension Benefits and Postretirement Benefits Other Than Pensions (Tables)

3 Months Ended

Sep. 30, 2015

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 Nine Months Ended
(Millions of Dollars)	September 30, 2015 (1)		September 30, 2014		September 30, 2015 (1)		September 30, 2014
Service Cost	$	22.7	$	19.1	$	68.7	$	60.7
Interest Cost		56.9		56.4		170.3		169.5
Expected Return on Plan Assets		(83.9)		(77.7)		(252.1)		(233.1)
Actuarial Loss		36.5		31.7		111.9		96.5
Prior Service Cost		0.9		1.1		2.7		3.3
Total Net Periodic Benefit Expense	$	33.1	$	30.6	$	101.5	$	96.9
Capitalized Pension Expense	$	9.8	$	8.3	$	31.3	$	26.7
	PBOP				PBOP
Eversource	For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2015 (1)		September 30, 2014		September 30, 2015 (1)		September 30, 2014
Service Cost	$	4.1	$	3.1	$	10.3	$	9.3
Interest Cost		11.8		12.4		30.4		37.1
Expected Return on Plan Assets		(16.9)		(15.8)		(43.2)		(47.4)
Actuarial Loss		1.7		3.0		4.5		9.1
Prior Service Credit		(0.1)		(0.7)		(0.3)		(2.1)
Total Net Periodic Benefit Expense	$	0.6	$	2.0	$	1.7	$	6.0
Capitalized PBOP Expense/(Income)	$	-	$	1.1	$	0.1	$	1.9

	Pension and SERP
	For the Three Months Ended September 30, 2015								For the Three Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH (1)		WMECO		CL&P		Electric		PSNH		WMECO
Service Cost	$	6.2	$	3.7	$	3.1	$	1.0	$	5.0	$	3.0	$	2.3	$	0.8
Interest Cost		12.9		10.0		6.1		2.6		12.5		10.3		5.7		2.5
Expected Return on Plan Assets		(19.8)		(17.5)		(10.1)		(4.7)		(18.7)		(15.7)		(9.3)		(4.4)
Actuarial Loss		8.0		8.7		2.9		1.6		8.2		5.9		2.8		1.7
Prior Service Cost		0.4		-		0.1		0.1		0.4		-		0.1		0.1
Total Net Periodic Benefit Expense	$	7.7	$	4.9	$	2.1	$	0.6	$	7.4	$	3.5	$	1.6	$	0.7
Intercompany Allocations	$	5.8	$	3.4	$	1.6	$	1.1	$	6.5	$	2.9	$	1.8	$	1.2
Capitalized Pension Expense	$	4.7	$	2.7	$	0.8	$	0.5	$	4.3	$	2.6	$	0.7	$	0.6
	Pension and SERP
	For the Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH (1)		WMECO		CL&P		Electric		PSNH		WMECO
Service Cost	$	18.4	$	11.2	$	9.0	$	3.2	$	15.2	$	10.6	$	7.4	$	2.7
Interest Cost		38.4		30.2		18.1		7.8		38.1		31.0		18.0		7.8
Expected Return on Plan Assets		(59.1)		(52.5)		(30.3)		(14.2)		(56.7)		(47.3)		(28.8)		(13.5)
Actuarial Loss		24.2		27.0		8.8		4.8		25.5		17.6		8.9		5.2
Prior Service Cost		1.1		0.1		0.4		0.2		1.4		-		0.5		0.3
Total Net Periodic Benefit Expense	$	23.0	$	16.0	$	6.0	$	1.8	$	23.5	$	11.9	$	6.0	$	2.5
Intercompany Allocations	$	18.0	$	10.3	$	5.0	$	3.3	$	20.8	$	6.7	$	6.0	$	3.9
Capitalized Pension Expense	$	14.1	$	8.6	$	2.6	$	1.4	$	13.6	$	5.5	$	2.4	$	2.0

	PBOP
	For the Three Months Ended September 30, 2015								For the Three Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH (1)		WMECO	CL&P		Electric		PSNH		WMECO
Service Cost	$	0.5	$	1.3	$	0.3	$	0.1	$	0.6	$	0.8	$	0.3	$	0.1
Interest Cost		1.8		4.8		1.0		0.3		2.0		4.9		1.1		0.4
Expected Return on Plan Assets		(2.8)		(6.8)		(1.5)		(0.6)		(2.6)		(6.5)		(1.4)		(0.6)
Actuarial Loss/(Gain)		0.2		0.6		0.1		-		1.0		(0.1)		0.6		0.1
Prior Service Credit		-		(0.1)		-		-		-		(0.5)		-		-
Total Net Periodic Benefit Expense/(Income)	$	(0.3)	$	(0.2)	$	(0.1)	$	(0.2)	$	1.0	$	(1.4)	$	0.6	$	0.0
Intercompany Allocations	$	0.4	$	0.2	$	0.1	$	0.1	$	0.9	$	0.3	$	0.2	$	0.2
Capitalized PBOP Expense/(Income)	$	(0.1)	$	-	$	0.1	$	-	$	0.5	$	(0.5)	$	0.2	$	-
	PBOP
	For the Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
			NSTAR									NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH (1)		WMECO	CL&P			Electric	PSNH		WMECO
Service Cost	$	1.6	$	4.0	$	1.0	$	0.3	$	1.7	$	2.3	$	1.0	$	0.3
Interest Cost		5.4		14.2		2.9		1.1		6.0		14.6		3.2		1.3
Expected Return on Plan Assets		(8.3)		(20.5)		(4.4)		(1.9)		(7.9)		(19.5)		(4.1)		(1.7)
Actuarial Loss/(Gain)		0.5		1.8		0.4		-		3.2		(0.4)		1.7		0.3
Prior Service Credit		-		(0.1)		-		-		-		(1.4)		-		-
Total Net Periodic Benefit Expense/(Income)	$	(0.8)	$	(0.6)	$	(0.1)	$	(0.5)	$	3.0	$	(4.4)	$	1.8	$	0.2
Intercompany Allocations	$	1.4	$	0.7	$	0.3	$	0.3	$	3.1	$	0.4	$	0.8	$	0.6
Capitalized PBOP Expense/(Income)	$	(0.2)	$	(0.1)	$	0.2	$	(0.1)	$	1.5	$	(1.5)	$	0.6	$	0.1
(1) Amounts exclude approximately $0.8 million and $2.4 million for the three and nine months ended September 30, 2015, respectively, that represented amounts included in other deferred debits.

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SEGMENT INFORMATION (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Operating Revenues	$ 1,933,105	$ 1,892,532	$ 6,263,597	$ 5,860,736
Operating Income	469,238	440,910	1,378,728	1,202,588
Total Interest Expense	(92,534)	(89,738)	(279,635)	(272,208)
Other Income/(Loss), Net	5,241	11,860	23,866	19,054
Income Tax Expense	(144,146)	(126,539)	(420,640)	(345,858)
Net Income	237,799	236,493	702,319	603,576
Net Income Attributable to Noncontrolling Interests	(1,879)	(1,879)	(5,639)	(5,639)
Net Income Attributable to Controlling Interests	235,920	234,614	696,680	597,937
Total Assets	30,046,026		30,046,026		$ 29,777,975
Investments in Property, Plant and Equipment			1,177,285	1,117,493
Electric Distribution Member
Segment Reporting Information [Line Items]
Operating Revenues	1,543,700	1,502,600	4,686,500	4,350,400
Depreciation And Amortization	(84,500)	(71,700)	(342,100)	(309,900)
Operating Expenses, Other	(1,140,800)	(1,141,500)	(3,535,700)	(3,343,900)
Operating Income	318,400	289,400	808,700	696,600
Total Interest Expense	(47,400)	(49,200)	(140,600)	(143,800)
Other Income/(Loss), Net	1,900	9,300	9,600	13,600
Net Income Attributable to Controlling Interests	167,500	153,400	418,900	349,100
Total Assets	17,836,800		17,836,800		17,563,400
Investments in Property, Plant and Equipment			506,500	480,100
Natural Gas Distribution [Member]
Segment Reporting Information [Line Items]
Operating Revenues	106,200	109,200	799,600	737,500
Depreciation And Amortization	(17,500)	(16,400)	(53,400)	(51,100)
Operating Expenses, Other	(92,700)	(98,400)	(631,500)	(586,200)
Operating Income	(4,000)	(5,600)	114,700	100,200
Total Interest Expense	(9,200)	(8,500)	(27,200)	(25,600)
Other Income/(Loss), Net	(200)	100	(100)	200
Net Income Attributable to Controlling Interests	(3,700)	(9,900)	57,300	44,200
Total Assets	2,986,000		2,986,000		3,030,900
Investments in Property, Plant and Equipment			120,000	120,600
Electric Transmission [Member]
Segment Reporting Information [Line Items]
Operating Revenues	270,400	262,500	787,200	721,400
Depreciation And Amortization	(42,400)	(37,400)	(122,600)	(111,400)
Operating Expenses, Other	(78,300)	(74,200)	(225,500)	(211,500)
Operating Income	149,700	150,900	439,100	398,500
Total Interest Expense	(25,900)	(24,500)	(79,800)	(78,800)
Other Income/(Loss), Net	3,800	2,700	11,900	6,900
Net Income Attributable to Controlling Interests	78,000	88,100	225,000	206,800
Total Assets	7,773,700		7,773,700		7,625,600
Investments in Property, Plant and Equipment			493,900	469,900
Other Segment [Member]
Segment Reporting Information [Line Items]
Operating Revenues	211,600	211,200	655,200	568,100
Depreciation And Amortization	(7,100)	(13,800)	(21,500)	(28,300)
Operating Expenses, Other	(199,600)	(192,400)	(619,400)	(534,100)
Operating Income	4,900	5,000	14,300	5,700
Total Interest Expense	(11,200)	(8,600)	(35,400)	(27,200)
Other Income/(Loss), Net	241,900	226,400	777,000	657,900
Net Income Attributable to Controlling Interests	234,900	228,300	764,700	653,400
Total Assets	12,750,000		12,750,000		12,682,500
Investments in Property, Plant and Equipment			56,900	46,900
Eliminations Segment [Member]
Segment Reporting Information [Line Items]
Operating Revenues	(198,800)	(193,000)	(664,900)	(516,700)
Depreciation And Amortization	500	8,600	1,600	12,700
Operating Expenses, Other	198,500	185,600	665,200	505,600
Operating Income	200	1,200	1,900	1,600
Total Interest Expense	1,200	1,000	3,400	3,200
Other Income/(Loss), Net	(242,200)	(226,600)	(774,500)	(659,500)
Net Income Attributable to Controlling Interests	(240,800)	(225,300)	(769,200)	(655,600)
Total Assets	(11,300,500)		(11,300,500)		(11,124,400)
Investments in Property, Plant and Equipment			0	0
Total [Member]
Segment Reporting Information [Line Items]
Operating Revenues	1,933,100	1,892,500	6,263,600	5,860,700
Depreciation And Amortization	(151,000)	(130,700)	(538,000)	(488,000)
Operating Expenses, Other	(1,312,900)	(1,320,900)	(4,346,900)	(4,170,100)
Operating Income	469,200	440,900	1,378,700	1,202,600
Total Interest Expense	(92,500)	(89,800)	(279,600)	(272,200)
Other Income/(Loss), Net	5,200	11,900	23,900	19,100
Net Income Attributable to Controlling Interests	235,900	$ 234,600	696,700	597,900
Total Assets	$ 30,046,000		30,046,000		$ 29,778,000
Investments in Property, Plant and Equipment			$ 1,177,300	$ 1,117,500

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Fair Value Measurements (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ (422.4)	$ (430.9)	$ (415.4)	$ (635.2)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	(6.0)	(13.6)	(55.3)	147.6
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	21.4	21.0	63.7	64.1
Ending Balance	(407.0)	(423.5)	(407.0)	(423.5)
The Connecticut Light And Power Company [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(420.2)	(424.6)	(410.9)	(630.6)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	(7.6)	(15.0)	(56.6)	149.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	20.9	18.5	60.6	60.1
Ending Balance	(406.9)	(421.1)	(406.9)	(421.1)
NSTAR Electric Company [Member]
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(2.2)	(6.3)	(4.5)	(7.3)
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Reg Asset Liability	1.6	1.4	1.3	0.9
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Settlements	0.5	2.5	3.1	4.0
Ending Balance	$ (0.1)	$ (2.4)	$ (0.1)	$ (2.4)

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Guarantees and Indemnifications (Tables)

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Guarantee Obligations Text Block

			Maximum Exposure
Company		Description	(in millions)		Expiration Dates
On behalf of subsidiaries:
	Various	Surety Bonds (1)	$	33.2	2015 - 2016
	Eversource Service and Rocky River Realty Company	Lease Payments for Vehicles and Real Estate	$	12.2	2019 and 2024
On behalf of external parties:
	Purchaser of E.S. Boulos Company and a bonding company	E.S. Boulos Company Indemnification	$	38.2	2016 and 2020
	Algonquin Gas Transmission, LLC	Access Northeast project
	(owner of Access Northeast assets)	capital contributions guarantee	$	206.0		2021

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Fair Value By Balance Sheet Grouping Text Block

	As of September 30, 2015				As of December 31, 2014
Eversource	Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	157.3	$	155.6	$	153.6
Long-Term Debt		8,986.4		9,419.6		8,851.6		9,451.2

	As of September 30, 2015
	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
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	115.4	$	43.0	$	41.9	$	-	$	-	$	-	$	-
Long-Term Debt		2,975.3		3,285.1		1,792.7		1,931.3		1,076.3		1,135.5		577.8		613.3
	As of December 31, 2014
	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
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	112.0	$	43.0	$	41.6	$	-	$	-	$	-	$	-
Long-Term Debt		2,842.0		3,214.5		1,797.4		1,993.5		1,076.3		1,137.9		628.5		689.4

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PROPERTY, PLANT AND ACCUMULATED DEPRECIATION

3 Months Ended

Sep. 30, 2015

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 September 30, 2015		As of December 31, 2014
(Millions of Dollars)		Eversource		Eversource
Distribution - Electric		$	12,821.6	$	12,495.2
Distribution - Natural Gas			2,657.5		2,595.4
Transmission			7,260.6		6,930.7
Generation			1,180.0		1,170.9
Electric and Natural Gas Utility			23,919.7		23,192.2
Other (1)			555.3		551.3
Property, Plant and Equipment, Gross			24,475.0		23,743.5
Less: Accumulated Depreciation
	Electric and Natural Gas Utility		(6,041.5)		(5,777.8)
	Other		(247.6)		(231.8)
Total Accumulated Depreciation			(6,289.1)		(6,009.6)
Property, Plant and Equipment, Net			18,185.9		17,733.9
Construction Work in Progress			1,220.1		913.1
Total Property, Plant and Equipment, Net		$	19,406.0	$	18,647.0

(1)These assets are primarily comprised of building improvements,computer software, hardware and equipment and telecommunications assets at Eversource Service andEversource's unregulated companies.

	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Distribution	$	5,289.6	$	5,001.9	$	1,772.0	$	798.1	$	5,158.8	$	4,895.5	$	1,696.7	$	784.2
Transmission		3,480.5		1,995.3		839.9		896.7		3,274.0		1,928.5		789.7		891.0
Generation		-		-		1,145.5		34.5		-		-		1,136.5		34.4
Property, Plant and Equipment, Gross		8,770.1		6,997.2		3,757.4		1,729.3		8,432.8		6,824.0		3,622.9		1,709.6
Less: Accumulated Depreciation		(2,007.9)		(1,857.9)		(1,149.6)		(302.6)		(1,928.0)		(1,761.4)		(1,090.0)		(297.4)
Property, Plant and Equipment, Net		6,762.2		5,139.3		2,607.8		1,426.7		6,504.8		5,062.6		2,532.9		1,412.2
Construction Work in Progress		246.4		405.8		160.4		105.0		304.9		272.8		102.9		49.1
Total Property, Plant and Equipment, Net	$	7,008.6	$	5,545.1	$	2,768.2	$	1,531.7	$	6,809.7	$	5,335.4	$	2,635.8	$	1,461.3

As of September 30, 2015, PSNH had $1.1 billion in gross generation utility plant assets and Accumulated Depreciation of $514 million. These generation assets are the subject of a divestiture agreement entered into on June 10, 2015 between Eversource, PSNH and key New Hampshire officials whereby, among other resolutions, PSNH has agreed to sell these generation assets. Upon completion of the sale, all remaining stranded costs will be recovered via bonds that will be secured by a non-bypassable charge on the bills of PSNH's customers. See Note 8E, "Commitments and Contingencies – PSNH Generation Restructuring," for further information.

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ACCUMULATED OTHER COMPREHENSIVE INCOME (Tables)

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Accumulated Other Comprehensive Income Loss Table Text Block

	For the Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
	Qualified		Unrealized						Qualified		Unrealized
	Cash Flow		Gains/(Losses)		Defined				Cash Flow		Gains on		Defined
Eversource	Hedging		on Marketable		Benefit				Hedging		Marketable		Benefit
(Millions of Dollars)	Instruments		Securities		Plans		Total		Instruments		Securities		Plans		Total
Balance as of Beginning of Period	$	(12.4)	$	0.7	$	(62.3)	$	(74.0)	$	(14.4)	$	0.4	$	(32.0)	$	(46.0)
OCI Before Reclassifications		-		(3.9)		(0.4)		(4.3)		-		0.2		1.2		1.4
Amounts Reclassified from AOCI		1.5		-		3.3		4.8		1.5		-		2.9		4.4
Net OCI		1.5		(3.9)		2.9		0.5		1.5		0.2		4.1		5.8
Balance as of End of Period	$	(10.9)	$	(3.2)	$	(59.4)	$	(73.5)	$	(12.9)	$	0.6	$	(27.9)	$	(40.2)

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Severance Benefits (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Notes To Consolidated Financial Statements [Abstract]
Postemployment Benefits Period Expense	$ 1.0	$ 0.7	$ 2.6	$ 6.5
Postemployment Benefits Liability Current	$ 7.1		$ 7.1		$ 10.4

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ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			$ (74,009)	$ (46,000)
Other Comprehensive Income Before Reclassifications, Net of Tax			(4,300)	1,400
Reclassification From OCI, Net Of Tax			4,800	4,400
Other Comprehensive Income (Loss), Net of Tax, Total	$ (1,513)	$ 1,335	463	5,859
AOCI Ending Balance	(73,546)	(40,200)	(73,546)	(40,200)
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Abstract]
Total Interest Expense	(92,534)	(89,738)	(279,635)	(272,208)
Income Tax Expense	(144,146)	(126,539)	(420,640)	(345,858)
Net Income Attributable to Controlling Interests	235,920	234,614	696,680	597,937
The Connecticut Light And Power Company [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(931)
Other Comprehensive Income (Loss), Net of Tax, Total	13	104	196	341
AOCI Ending Balance	(735)		(735)
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Abstract]
Total Interest Expense	(36,716)	(38,735)	(109,463)	(110,448)
Income Tax Expense	(46,569)	(30,038)	(127,845)	(95,980)
Public Service Company Of New Hampshire [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(7,369)
Other Comprehensive Income (Loss), Net of Tax, Total	122	277	636	885
AOCI Ending Balance	(6,733)		(6,733)
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Abstract]
Total Interest Expense	(11,647)	(11,024)	(34,582)	(33,995)
Income Tax Expense	(20,158)	(17,603)	(56,135)	(52,199)
Western Massachusetts Electric Company [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(3,176)
Other Comprehensive Income (Loss), Net of Tax, Total	74	83	232	256
AOCI Ending Balance	(2,944)		(2,944)
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Abstract]
Total Interest Expense	(5,901)	(6,576)	(19,014)	(18,929)
Income Tax Expense	(9,749)	(10,490)	(28,555)	(26,596)
Qualified Cash Flow Hedging Instruments [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(12,400)	(14,400)
Reclassification From OCI, Net Of Tax			1,500	1,500
Other Comprehensive Income (Loss), Net of Tax, Total			1,500	1,500
AOCI Ending Balance	(10,900)	(12,900)	(10,900)	(12,900)
Unrealized Gains Losses on Available for Sale Securities [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			700	400
Other Comprehensive Income Before Reclassifications, Net of Tax			(3,900)	200
Other Comprehensive Income (Loss), Net of Tax, Total			(3,900)	200
AOCI Ending Balance	(3,200)	600	(3,200)	600
Pension, SERP and PBOP Benefit Plans [Member]
Accumulated Other Comprehensive Income Loss Net Of Tax RollForward [Abstract]
AOCI Beginning Balance			(62,300)	(32,000)
Other Comprehensive Income Before Reclassifications, Net of Tax			(400)	1,200
Reclassification From OCI, Net Of Tax			3,300	2,900
Other Comprehensive Income (Loss), Net of Tax, Total			2,900	4,100
AOCI Ending Balance	$ (59,400)	$ (27,900)	$ (59,400)	$ (27,900)

XML

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Current Assets:
Cash	$ 35,781	$ 38,703
Receivables, Net	928,064	856,346
Unbilled Revenues	197,920	211,758
Taxes Receivable	12,247	337,307
Fuel, Materials and Supplies	302,225	349,664
Regulatory Assets Current	653,892	672,493
Marketable Securities - Current	119,702	124,173
Prepayments and Other Current Assets	117,857	102,021
Total Current Assets	2,367,688	2,692,465
Property, Plant and Equipment, Net	19,406,025	18,647,041
Deferred Debits and Other Assets:
Regulatory Assets Long Term	3,951,752	4,054,086
Goodwill	3,519,401	3,519,401
Marketable Securities	476,778	515,025
Other Long-Term Assets	324,382	349,957
Total Deferred Debits and Other Assets	8,272,313	8,438,469
Total Assets	30,046,026	29,777,975
Current Liabilities:
Notes Payable	1,015,500	956,825
Long-Term Debt - Current Portion	228,883	245,583
Accounts Payable - Current	610,753	868,231
Obligations to Third Party Suppliers	157,798	115,632
Regulatory Liability Current	226,061	235,022
Deferred Tax Liabilities Current	169,272	160,288
Other Liabilities - Current	563,426	552,800
Total Current Liabilities	2,971,693	3,134,381
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	4,612,828	4,467,473
Regulatory Liabilities Long-Term	517,595	515,144
Long-Term Derivative Liabilities	365,692	409,632
Accrued Pension, SERP and PBOP	1,498,346	1,638,558
Other Long-Term Liabilities	872,376	874,387
Total Deferred Credits and Other Liabilities	7,866,837	7,905,194
Capitalization:
Long-Term Debt	8,757,498	8,606,017
Noncontrolling Interest in Consolidated Subsidiary:
Temporary Equity, Carrying Amount, Attributable to Noncontrolling Interest	155,568	155,568
Common Shareholders' Equity:
Common Stock	1,669,313	1,666,796
Capital Surplus, Paid In	6,260,663	6,235,834
Retained Earnings	2,747,977	2,448,661
Accumulated Other Comprehensive Loss	(73,546)	(74,009)
Treasury Stock	(309,977)	(300,467)
Common Shareholders' Equity	10,294,430	9,976,815
Total Capitalization	19,207,496	18,738,400
Total Liabilities and Capitalization	30,046,026	29,777,975
The Connecticut Light And Power Company [Member]
Current Assets:
Cash	13,407	2,356
Receivables, Net	425,955	355,140
Accounts Receivable from Affiliated Companies	28,266	16,757
Unbilled Revenues	96,301	102,137
Taxes Receivable	0	116,148
Regulatory Assets Current	243,293	220,344
Materials and Supplies	44,306	46,664
Prepaid Taxes	52,351	15,597
Prepayments and Other Current Assets	16,239	22,225
Total Current Assets	920,118	897,368
Property, Plant and Equipment, Net	7,008,603	6,809,664
Deferred Debits and Other Assets:
Regulatory Assets Long Term	1,420,974	1,475,508
Other Long-Term Assets	145,031	177,568
Total Deferred Debits and Other Assets	1,566,005	1,653,076
Total Assets	9,494,726	9,360,108
Current Liabilities:
Notes Payable To Affiliated Companies	0	133,400
Long-Term Debt - Current Portion	0	162,000
Accounts Payable - Current	207,366	272,971
Accounts Payable to Affiliated Companies	93,257	65,594
Obligations to Third Party Suppliers	75,659	73,624
Regulatory Liability Current	136,393	124,722
Accrued Taxes	47,973	4,091
Derivative Liabilities - Current	91,372	88,459
Other Liabilities - Current	124,504	149,329
Total Current Liabilities	776,524	1,074,190
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,636,831	1,642,805
Regulatory Liabilities Long-Term	76,864	81,298
Long-Term Derivative Liabilities	364,691	406,199
Accrued Pension, SERP and PBOP	284,890	273,854
Other Long-Term Liabilities	143,642	148,844
Total Deferred Credits and Other Liabilities	2,506,918	2,553,000
Capitalization:
Long-Term Debt	2,975,316	2,679,951
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	1,910,651	1,804,869
Retained Earnings	1,149,500	1,072,477
Accumulated Other Comprehensive Loss	(735)	(931)
Common Shareholders' Equity	3,119,768	2,936,767
Total Capitalization	6,211,284	5,732,918
Total Liabilities and Capitalization	9,494,726	9,360,108
NSTAR Electric Company [Member]
Current Assets:
Cash	2,809	12,773
Receivables, Net	303,969	234,481
Accounts Receivable from Affiliated Companies	17,229	40,353
Unbilled Revenues	43,288	29,741
Taxes Receivable	0	144,601
Fuel, Materials and Supplies	52,315	74,179
Regulatory Assets Current	223,520	198,710
Prepayments and Other Current Assets	8,862	10,815
Total Current Assets	651,992	745,653
Property, Plant and Equipment, Net	5,545,082	5,335,436
Deferred Debits and Other Assets:
Regulatory Assets Long Term	1,179,996	1,179,100
Other Long-Term Assets	60,339	73,051
Total Deferred Debits and Other Assets	1,240,335	1,252,151
Total Assets	7,437,409	7,333,240
Current Liabilities:
Notes Payable	258,500	302,000
Long-Term Debt - Current Portion	200,000	4,700
Accounts Payable - Current	172,521	217,311
Accounts Payable to Affiliated Companies	25,515	63,517
Obligations to Third Party Suppliers	70,607	34,824
Renewable Portfolio Standards Compliance Obligation	67,828	35,698
Regulatory Liability Current	12,319	49,611
Accrued Taxes	66,474	4,191
Deferred Tax Liabilities Current	92,183	55,136
Other Liabilities - Current	88,905	111,800
Total Current Liabilities	1,054,852	878,788
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,546,801	1,527,667
Regulatory Liabilities Long-Term	267,342	262,738
Accrued Pension, SERP and PBOP	211,891	235,529
Other Long-Term Liabilities	122,026	129,279
Total Deferred Credits and Other Liabilities	2,148,060	2,155,213
Capitalization:
Long-Term Debt	1,592,727	1,792,712
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	994,130
Retained Earnings	1,603,134	1,468,955
Accumulated Other Comprehensive Loss	258	442
Common Shareholders' Equity	2,598,770	2,463,527
Total Capitalization	4,234,497	4,299,239
Total Liabilities and Capitalization	7,437,409	7,333,240
Public Service Company Of New Hampshire [Member]
Current Assets:
Cash	2,103	489
Receivables, Net	91,700	80,151
Accounts Receivable from Affiliated Companies	14,630	3,194
Unbilled Revenues	34,932	40,181
Fuel, Materials and Supplies	143,983	148,139
Regulatory Assets Current	89,513	111,705
Prepayments and Other Current Assets	22,125	42,392
Total Current Assets	398,986	426,251
Property, Plant and Equipment, Net	2,768,206	2,635,844
Deferred Debits and Other Assets:
Regulatory Assets Long Term	272,360	293,115
Other Long-Term Assets	35,075	39,228
Total Deferred Debits and Other Assets	307,435	332,343
Total Assets	3,474,627	3,394,438
Current Liabilities:
Notes Payable To Affiliated Companies	137,300	90,500
Accounts Payable - Current	76,330	93,349
Accounts Payable to Affiliated Companies	25,239	33,734
Regulatory Liability Current	11,338	16,044
Deferred Tax Liabilities Current	34,699	36,164
Other Liabilities - Current	47,589	38,969
Total Current Liabilities	332,495	308,760
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	629,055	587,292
Regulatory Liabilities Long-Term	49,680	51,372
Accrued Pension, SERP and PBOP	97,167	93,243
Other Long-Term Liabilities	48,543	50,155
Total Deferred Credits and Other Liabilities	824,445	782,062
Capitalization:
Long-Term Debt	1,076,336	1,076,286
Common Shareholders' Equity:
Common Stock	0	0
Capital Surplus, Paid In	748,634	748,240
Retained Earnings	499,450	486,459
Accumulated Other Comprehensive Loss	(6,733)	(7,369)
Common Shareholders' Equity	1,241,351	1,227,330
Total Capitalization	2,317,687	2,303,616
Total Liabilities and Capitalization	3,474,627	3,394,438
Western Massachusetts Electric Company [Member]
Current Assets:
Cash	658	0
Receivables, Net	62,889	51,066
Accounts Receivable from Affiliated Companies	24,221	7,851
Unbilled Revenues	14,517	15,146
Taxes Receivable	49	18,126
Regulatory Assets Current	48,805	51,923
Marketable Securities - Current	40,459	28,658
Prepayments and Other Current Assets	6,983	7,607
Total Current Assets	198,581	180,377
Property, Plant and Equipment, Net	1,531,705	1,461,321
Deferred Debits and Other Assets:
Regulatory Assets Long Term	133,697	146,307
Marketable Securities	17,888	29,452
Other Long-Term Assets	26,709	22,018
Total Deferred Debits and Other Assets	178,294	197,777
Total Assets	1,908,580	1,839,475
Current Liabilities:
Notes Payable To Affiliated Companies	126,200	21,400
Long-Term Debt - Current Portion	0	50,000
Accounts Payable - Current	33,960	53,732
Accounts Payable to Affiliated Companies	21,496	14,328
Regulatory Liability Current	24,267	22,486
Deferred Tax Liabilities Current	13,403	18,089
Other Liabilities - Current	28,961	24,080
Total Current Liabilities	248,287	204,115
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	422,753	416,822
Regulatory Liabilities Long-Term	11,926	10,835
Accrued Pension, SERP and PBOP	18,320	17,705
Other Long-Term Liabilities	36,849	33,747
Total Deferred Credits and Other Liabilities	489,848	479,109
Capitalization:
Long-Term Debt	577,781	578,471
Common Shareholders' Equity:
Common Stock	10,866	10,866
Capital Surplus, Paid In	391,398	391,256
Retained Earnings	193,344	178,834
Accumulated Other Comprehensive Loss	(2,944)	(3,176)
Common Shareholders' Equity	592,664	577,780
Total Capitalization	1,170,445	1,156,251
Total Liabilities and Capitalization	$ 1,908,580	$ 1,839,475

XML

MARKETABLE SECURITIES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Investments, Debt and Equity Securities [Abstract]
Marketable Securities, Restricted	$ 430.2		$ 430.2		$ 450.8
Available For Sale Securities Debt Maturities Fair Value Abstract
Available For Sale Securities Debt Maturities After Five Through Ten Years Fair Value	56.9		56.9
Available For Sale Securities Debt Maturities After Ten Years Fair Value	121.4		121.4
Available For Sale Securities Debt Maturities After One Year Through Five Years Fair Value	68.0		68.0
Available For Sale Securities Debt Maturities Within One Year Fair Value	68.1		68.1
Available For Sale Securities Debt Maturities Fair Value	314.4		314.4
Available For Sale Securities Debt Maturities Amortized Cost Abstract
Available For Sale Securities Debt Maturities After One Through Five Years Amortized Cost	67.6		67.6
Available For Sale Securities Debt Maturities Within One Year Amortized Cost	68.1		68.1
Available For Sale Securities Debt Maturities After Ten Years Amortized Cost	119.0		119.0
Available For Sale Securities Debt Maturities After Five Through Ten Years Amortized Cost	56.9		56.9
Available For Sale Securities Debt Maturities Amortized Cost	311.6		311.6
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	596.5		596.5		639.2
TradingSecuritiesEquity	14.2		14.2		85.1
IncreaseDecreaseInTradingSecurities	(0.5)	$ (1.9)	1.6	$ 1.9
Western Massachusetts Electric Company [Member]
Available For Sale Securities Debt Maturities Fair Value Abstract
Available For Sale Securities Debt Maturities After Five Through Ten Years Fair Value	0.5		0.5
Available For Sale Securities Debt Maturities After Ten Years Fair Value	3.1		3.1
Available For Sale Securities Debt Maturities After One Year Through Five Years Fair Value	14.2		14.2
Available For Sale Securities Debt Maturities Within One Year Fair Value	40.5		40.5
Available For Sale Securities Debt Maturities Fair Value	58.3		58.3
Available For Sale Securities Debt Maturities Amortized Cost Abstract
Available For Sale Securities Debt Maturities After One Through Five Years Amortized Cost	14.2		14.2
Available For Sale Securities Debt Maturities Within One Year Amortized Cost	40.5		40.5
Available For Sale Securities Debt Maturities After Ten Years Amortized Cost	3.1		3.1
Available For Sale Securities Debt Maturities After Five Through Ten Years Amortized Cost	0.5		0.5
Available For Sale Securities Debt Maturities Amortized Cost	58.3		58.3
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	58.3		58.3		58.1
Fair Value Inputs Level 1 Member
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	312.8		312.8		343.9
Fair Value Inputs Level 1 Member | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	8.0		8.0		4.3
Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	283.7		283.7		295.3
Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	50.3		50.3		53.8
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	41.3		41.3		51.3
US Government Debt Securities Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	0.0		0.0		0.0
Corporate Bond Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	57.5		57.5		49.1
Corporate Bond Securities Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	12.2		12.2		14.7
Asset Backed Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	27.9		27.9		54.1
Asset Backed Securities Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	7.6		7.6		14.5
Municipal Bonds Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	123.9		123.9		116.3
Municipal Bonds Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	10.3		10.3		13.0
Other Debt Securities Member | Fair Value Inputs Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	33.1		33.1		24.5
Other Debt Securities Member | Fair Value Inputs Level 2 [Member] | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	20.2		20.2		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	30.7		30.7		24.9
Cash And Cash Equivalents Member | Fair Value Inputs Level 1 Member | Western Massachusetts Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	8.0		8.0		4.3
Mutual Funds [Member] | Fair Value Inputs Level 1 Member
Fair Value Assets And Liabilities Measured On Recurring Basis Abstract
Investments Fair Value Disclosure	282.1		282.1		319.0
Debt Securities
Investments, Debt and Equity Securities [Abstract]
Available For Sale Securities Fair Value Disclosure	314.4		314.4		320.2
Available-for-sale Securities, Gross Unrealized Gains	3.6				7.5
AvailableForSaleSecuritiesGrossUnrealizedLoss	(0.8)				(0.3)
Available For Sale Securities Amortized Cost	311.6		311.6		313.0
Debt Securities | Western Massachusetts Electric Company [Member]
Investments, Debt and Equity Securities [Abstract]
Available For Sale Securities Fair Value Disclosure	58.3		58.3		58.1
Available-for-sale Securities, Gross Unrealized Gains	0.0				0.0
AvailableForSaleSecuritiesGrossUnrealizedLoss	0.0				(0.1)
Available For Sale Securities Amortized Cost	58.3		58.3		58.2
Equity Securities
Investments, Debt and Equity Securities [Abstract]
Available For Sale Securities Fair Value Disclosure	267.9		267.9		233.9
Available-for-sale Securities, Gross Unrealized Gains	53.9				73.3
AvailableForSaleSecuritiesGrossUnrealizedLoss	(6.0)				0.0
Available For Sale Securities Amortized Cost	$ 220.0		$ 220.0		$ 160.6

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

3 Months Ended

Sep. 30, 2015

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 CONSOLIDATED 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 consolidatedfinancial 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.

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

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 entirety of this combined Quarterly Report on Form 10-Q, the first and second quarter 2015 combined Quarterly Report on Form 10-Qand the 2014 combined Annual Report on Form 10-K of Eversource, CL&P, NSTAR Electric, PSNH and WMECO, which were 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 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 September 30, 2015 and December31, 2014, the results of operations andcomprehensive income for the three and nine months ended September 30, 2015 and 2014, and the cash flows for the nine months ended September 30, 2015 and 2014. The results of operations and comprehensive incomefor the three and nine months ended September 30, 2015 and 2014 and the cash flows for the nine months ended September 30, 2015 and 2014 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.

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 accompanyingfinancial statements to conform to the current period presentation.

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, as a result of which ASU 2014-09 is required to be applied in the first quarter of 2018, with 2017 application permitted. The Company is reviewing the requirements of ASU 2014-09 and will implement the standard in the first quarter of 2018. The ASU is not expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

In April 2015, the FASB issued ASU 2015-03, Simplifying the Presentation of Debt Issuance Costs, that changes the balance sheet presentation of debt issuance costs. Under the standard, issuance costs related to debt will be presented on the balance sheet as a direct deduction from the carrying amount of the debt liability rather than as a deferred cost as required by current guidance. The new accounting guidance is effective for interim and annual periods beginning in the first quarter of 2016 with early adoption permitted. Upon adoption, an entity must apply the new guidance retrospectively to all prior periods presented in the financial statements. The Company intends to adopt the new guidance at December 31, 2015. Management does not expect the adoption of this standard to have a material effect on the financial statements of Eversource, CL&P, NSTAR Electric, PSNH or WMECO.

C.Provision for Uncollectible Accounts

Eversource, including CL&P, NSTAR Electric, PSNH and WMECO, presents its receivables at estimated net realizable value by maintaining a provision for uncollectible accounts. This provision is determined based upon a variety of judgments and factors, including the application of an estimated uncollectible percentage to each receivable aging category. The estimate is based upon historical collection and write-off experience and management's 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 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 to also recover in rates amounts associated with certain uncollectible hardship accounts receivable. Uncollectible customer account balances, which are expected to be recovered in rates, are included in Regulatory Assets or Other Long-Term Assets.

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

	Total Provision for Uncollectible Accounts				Uncollectible Hardship
(Millions of Dollars)	As of September 30, 2015		As of December 31, 2014		As of September 30, 2015		As of December 31, 2014
Eversource	$	185.8	$	175.3	$	86.6	$	91.5
CL&P		79.5		84.3		64.9		74.0
NSTAR Electric		46.4		40.7		-		-
PSNH		9.4		7.7		-		-
WMECO		13.2		9.9		7.7		6.2

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 and nonrecurring fair value measurements of nonfinancial assets such as goodwill and AROs, and is also used to estimate the 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. 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 payments in Taxes Other Than Income Taxes on the statements of income as follows:

	For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2015		September 30, 2014		September 30, 2015		September 30, 2014
Eversource	$	37.8	$	35.0	$	112.9	$	114.6
CL&P		35.5		32.5		98.0		99.0

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

G.	Supplemental Cash Flow Information
Non-cash investing activities include plant additions included in Accounts Payable as follows:
(Millions of Dollars)		As of September 30, 2015		As of September 30, 2014
Eversource		$	160.7		128.9
CL&P			46.0		52.2
NSTAR Electric			31.2		18.1
PSNH			33.8		21.0
WMECO			15.5		10.0

H.       Severance Benefits

Eversource recorded severance benefit expense of $1million and $0.7million for the three months ended September 30, 2015 and 2014, respectively, and $2.6million and $6.5million for the nine months ended September 30, 2015 and 2014, respectively, in connection with reorganizational and cost saving initiatives, and, in 2014, the partial outsourcing of information technology functions. As of September 30, 2015 and December31, 2014, the severance accrual totaled $7.1million and $10.4million, respectively, and was included in Other Current Liabilities on the balance sheets.

I.       Income Taxes

Income tax expense is estimated for each of the jurisdictions in which Eversource operates and is recorded on the quarter using an estimated annualized effective tax rate. This process to record income tax expense involves estimating current and deferred income tax expense or benefit and the impact of temporary differences resulting from differing treatment of items for financial reporting and income tax return reporting purposes. Such differences are the result of timing of the deduction for expenses, as well as any impact of permanent differences, non-tax deductible expenses, or other items that directly impact the income tax return as a result of a regulatory activity (flow-through items). The temporary differences and flow-through items result in deferred tax assets and liabilities that are included in the balance sheets.

Part of the annual process in making adjustments to these estimates is reconciling the provision for income taxes made during the income tax estimation process to what was filed in the income tax return (return to provision). In the third quarter of 2015, Eversource and CL&P recorded an $8 million and $4.2 million charge, respectively, as a result of reconciling and adjusting its 2014 provision for income taxes to what was filed on its 2014 income tax return. Concurrently, Eversource and CL&P recorded a reversal of state tax reserves in the third quarter of 2015, which resulted in a $5.9 million and $2.2 million benefit, respectively.

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SEGMENT INFORMATION (Tables)

3 Months Ended

Sep. 30, 2015

Segment Reporting Information [Line Items]

Schedule Of Segment Reporting Information By Segment Text Block

	For the Three Months Ended September 30, 2015
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	1,543.7	$	106.2	$	270.4	$	211.6	$	(198.8)	$	1,933.1
Depreciation and Amortization		(84.5)		(17.5)		(42.4)		(7.1)		0.5		(151.0)
Other Operating Expenses		(1,140.8)		(92.7)		(78.3)		(199.6)		198.5		(1,312.9)
Operating Income		318.4		(4.0)		149.7		4.9		0.2		469.2
Interest Expense		(47.4)		(9.2)		(25.9)		(11.2)		1.2		(92.5)
Other Income, Net		1.9		(0.2)		3.8		241.9		(242.2)		5.2
Net Income Attributable to Common Shareholders	$	167.5	$	(3.7)	$	78.0	$	234.9	$	(240.8)	$	235.9
	For the Nine Months Ended September 30, 2015
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	4,686.5	$	799.6	$	787.2	$	655.2	$	(664.9)	$	6,263.6
Depreciation and Amortization		(342.1)		(53.4)		(122.6)		(21.5)		1.6		(538.0)
Other Operating Expenses		(3,535.7)		(631.5)		(225.5)		(619.4)		665.2		(4,346.9)
Operating Income		808.7		114.7		439.1		14.3		1.9		1,378.7
Interest Expense		(140.6)		(27.2)		(79.8)		(35.4)		3.4		(279.6)
Other Income, Net		9.6		(0.1)		11.9		777.0		(774.5)		23.9
Net Income Attributable to Common Shareholders	$	418.9	$	57.3	$	225.0	$	764.7	$	(769.2)	$	696.7
Cash Flows Used for Investments in Plant	$	506.5	$	120.0	$	493.9	$	56.9	$	-	$	1,177.3

	For the Three Months Ended September 30, 2014
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	1,502.6	$	109.2	$	262.5	$	211.2	$	(193.0)	$	1,892.5
Depreciation and Amortization		(71.7)		(16.4)		(37.4)		(13.8)		8.6		(130.7)
Other Operating Expenses		(1,141.5)		(98.4)		(74.2)		(192.4)		185.6		(1,320.9)
Operating Income/(Loss)		289.4		(5.6)		150.9		5.0		1.2		440.9
Interest Expense		(49.2)		(8.5)		(24.5)		(8.6)		1.0		(89.8)
Other Income, Net		9.3		0.1		2.7		226.4		(226.6)		11.9
Net Income/Loss) Attributable to Common Shareholders	$	153.4	$	(9.9)	$	88.1	$	228.3	$	(225.3)	$	234.6
	For the Nine Months Ended September 30, 2014
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	4,350.4	$	737.5	$	721.4	$	568.1	$	(516.7)	$	5,860.7
Depreciation and Amortization		(309.9)		(51.1)		(111.4)		(28.3)		12.7		(488.0)
Other Operating Expenses		(3,343.9)		(586.2)		(211.5)		(534.1)		505.6		(4,170.1)
Operating Income		696.6		100.2		398.5		5.7		1.6		1,202.6
Interest Expense		(143.8)		(25.6)		(78.8)		(27.2)		3.2		(272.2)
Other Income, Net		13.6		0.2		6.9		657.9		(659.5)		19.1
Net Income Attributable to Common Shareholders	$	349.1	$	44.2	$	206.8	$	653.4	$	(655.6)	$	597.9
Cash Flows Used for Investments in Plant	$	480.1	$	120.6	$	469.9	$	46.9	$	-	$	1,117.5
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 September 30, 2015	$	17,836.8	$	2,986.0	$	7,773.7	$	12,750.0	$	(11,300.5)	$	30,046.0
As of December 31, 2014		17,563.4		3,030.9		7,625.6		12,682.5		(11,124.4)		29,778.0

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Other Taxes (Tables)

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

State Of Connecticut Gross Earnings Taxes [Table Text Block]

	For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2015		September 30, 2014		September 30, 2015		September 30, 2014
Eversource	$	37.8	$	35.0	$	112.9	$	114.6
CL&P		35.5		32.5		98.0		99.0

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Basis of Presentation (Details)	3 Months Ended
	Sep. 30, 2015
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.

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REGULATORY ACCOUNTING (Tables)

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Regulatory Assets Text Block

	As of September 30, 2015		As of December 31, 2014
(Millions of Dollars)	Eversource		Eversource
Benefit Costs	$	1,941.8	$	2,016.0
Derivative Liabilities		412.8		425.5
Income Taxes, Net		635.8		635.3
Storm Restoration Costs		461.3		502.8
Goodwill-related		490.0		505.4
Regulatory Tracker Mechanisms		373.1		350.5
Contractual Obligations - Yankee Companies		142.0		123.8
Other Regulatory Assets		148.9		167.3
Total Regulatory Assets		4,605.7		4,726.6
Less: Current Portion		653.9		672.5
Total Long-Term Regulatory Assets	$	3,951.8	$	4,054.1

	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Benefit Costs	$	434.8	$	486.8	$	171.1	$	84.2	$	445.4	$	515.9	$	174.3	$	85.0
Derivative Liabilities		406.9		1.4		-		-		410.9		4.5		-		-
Income Taxes, Net		435.7		83.5		34.2		30.5		437.7		83.7		38.0		35.5
Storm Restoration Costs		286.5		113.5		36.3		25.0		319.6		103.7		47.7		31.8
Goodwill-related		-		420.7		-		-		-		433.9		-		-
Regulatory Tracker Mechanisms		16.0		228.0		85.4		30.1		16.1		141.4		103.5		33.0
Other Regulatory Assets		84.4		69.6		34.9		12.7		66.1		94.7		41.3		12.9
Total Regulatory Assets		1,664.3		1,403.5		361.9		182.5		1,695.8		1,377.8		404.8		198.2
Less: Current Portion		243.3		223.5		89.5		48.8		220.3		198.7		111.7		51.9
Total Long-Term Regulatory Assets	$	1,421.0	$	1,180.0	$	272.4	$	133.7	$	1,475.5	$	1,179.1	$	293.1	$	146.3

Schedule Of Regulatory Liabilities Text Block

	As of September 30, 2015		As of December 31, 2014
(Millions of Dollars)	Eversource		Eversource
Cost of Removal	$	433.7	$	439.9
Regulatory Tracker Mechanisms		215.9		192.3
AFUDC - Transmission		66.2		67.1
Other Regulatory Liabilities		27.9		50.8
Total Regulatory Liabilities		743.7		750.1
Less: Current Portion		226.1		235.0
Total Long-Term Regulatory Liabilities	$	517.6	$	515.1

	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Cost of Removal	$	17.2	$	257.7	$	49.1	$	2.0	$	19.7	$	258.3	$	50.3	$	1.1
Regulatory Tracker Mechanisms		131.1		13.0		8.6		24.2		122.6		20.7		14.2		22.3
AFUDC - Transmission		51.8		5.4		-		9.0		53.6		4.4		-		9.1
Other Regulatory Liabilities		13.2		3.5		3.3		1.0		10.1		28.9		2.9		0.8
Total Regulatory Liabilities		213.3		279.6		61.0		36.2		206.0		312.3		67.4		33.3
Less: Current Portion		136.4		12.3		11.3		24.3		124.7		49.6		16.0		22.5
Total Long-Term Regulatory Liabilities	$	76.9	$	267.3	$	49.7	$	11.9	$	81.3	$	262.7	$	51.4	$	10.8

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REGULATORY ACCOUNTING

3 Months Ended

Sep. 30, 2015

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 consider 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 that 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 are as follows:

	As of September 30, 2015		As of December 31, 2014
(Millions of Dollars)	Eversource		Eversource
Benefit Costs	$	1,941.8	$	2,016.0
Derivative Liabilities		412.8		425.5
Income Taxes, Net		635.8		635.3
Storm Restoration Costs		461.3		502.8
Goodwill-related		490.0		505.4
Regulatory Tracker Mechanisms		373.1		350.5
Contractual Obligations - Yankee Companies		142.0		123.8
Other Regulatory Assets		148.9		167.3
Total Regulatory Assets		4,605.7		4,726.6
Less: Current Portion		653.9		672.5
Total Long-Term Regulatory Assets	$	3,951.8	$	4,054.1

	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Benefit Costs	$	434.8	$	486.8	$	171.1	$	84.2	$	445.4	$	515.9	$	174.3	$	85.0
Derivative Liabilities		406.9		1.4		-		-		410.9		4.5		-		-
Income Taxes, Net		435.7		83.5		34.2		30.5		437.7		83.7		38.0		35.5
Storm Restoration Costs		286.5		113.5		36.3		25.0		319.6		103.7		47.7		31.8
Goodwill-related		-		420.7		-		-		-		433.9		-		-
Regulatory Tracker Mechanisms		16.0		228.0		85.4		30.1		16.1		141.4		103.5		33.0
Other Regulatory Assets		84.4		69.6		34.9		12.7		66.1		94.7		41.3		12.9
Total Regulatory Assets		1,664.3		1,403.5		361.9		182.5		1,695.8		1,377.8		404.8		198.2
Less: Current Portion		243.3		223.5		89.5		48.8		220.3		198.7		111.7		51.9
Total Long-Term Regulatory Assets	$	1,421.0	$	1,180.0	$	272.4	$	133.7	$	1,475.5	$	1,179.1	$	293.1	$	146.3

Regulatory Costs in Other Long-Term Assets:The Regulated companies had $59.4million ($2.4million for CL&P, $21.1million for NSTAR Electric,$3.2 million for PSNH and $16.2million for WMECO) and $60.5million ($1.3 million for CL&P, $33.2million for NSTAR Electric, $0.9 million for PSNH, and $11million for WMECO) of additional regulatory costs as of September 30, 2015 and December 31, 2014, respectively, that were included in Other Long-Term Assets on the balance sheets. These amounts represent incurred costs for which recovery has not yet been specifically approved by the applicable regulatory agency. However, based on regulatory policies or past precedent on similar costs, management believes it is probable that these costs will ultimately be approved and recovered from customers in rates. The NSTAR Electric balance as of September 30, 2015 and December 31, 2014 primarily related to costs deferred in connection with the basic service bad debt adder. See below, within the "2015 Regulatory Developments" section of this footnote for further information.

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

	As of September 30, 2015		As of December 31, 2014
(Millions of Dollars)	Eversource		Eversource
Cost of Removal	$	433.7	$	439.9
Regulatory Tracker Mechanisms		215.9		192.3
AFUDC - Transmission		66.2		67.1
Other Regulatory Liabilities		27.9		50.8
Total Regulatory Liabilities		743.7		750.1
Less: Current Portion		226.1		235.0
Total Long-Term Regulatory Liabilities	$	517.6	$	515.1

	As of September 30, 2015								As of December 31, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH		WMECO		CL&P		Electric		PSNH		WMECO
Cost of Removal	$	17.2	$	257.7	$	49.1	$	2.0	$	19.7	$	258.3	$	50.3	$	1.1
Regulatory Tracker Mechanisms		131.1		13.0		8.6		24.2		122.6		20.7		14.2		22.3
AFUDC - Transmission		51.8		5.4		-		9.0		53.6		4.4		-		9.1
Other Regulatory Liabilities		13.2		3.5		3.3		1.0		10.1		28.9		2.9		0.8
Total Regulatory Liabilities		213.3		279.6		61.0		36.2		206.0		312.3		67.4		33.3
Less: Current Portion		136.4		12.3		11.3		24.3		124.7		49.6		16.0		22.5
Total Long-Term Regulatory Liabilities	$	76.9	$	267.3	$	49.7	$	11.9	$	81.3	$	262.7	$	51.4	$	10.8

2015 Regulatory Developments:

FERC ROE Complaints:As a result of the March 3, 2015 FERC order in the pending ROE complaint proceedings described in Note 8C, "Commitments and Contingencies – FERC ROE Complaints," in 2015, Eversource recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO. The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues.

NSTAR Electric and NSTAR Gas 2014 Comprehensive Settlement Agreement: On March 2, 2015, the DPU approved the comprehensive settlement agreement between NSTAR Electric, NSTAR Gas and the Massachusetts Attorney General (the "Settlement") as filed with the DPU on December31, 2014. The Settlement resolved the outstanding NSTAR Electric CPSL program filings for 2006 through 2011, the NSTAR Electric and NSTAR Gas PAM and energy efficiency-related customer billing adjustments reported in 2012, and the recovery of LBR related to NSTAR Electric's energy efficiency programs for 2009 through 2011 (11 dockets in total). In 2015, as a result of the DPU order, NSTAR Electric and NSTAR Gas commenced refunding a combined $44.7 million to customers, which was recorded as a regulatory liability. NSTAR Electric recognized a $21.7 million pre-tax benefit in the first quarter of 2015 as a result of the approval of the Settlement.

NSTAR Electric Basic Service Bad Debt Adder: On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006. As a result of the DPU order, NSTAR Electric increased its regulatory assets and reduced operations and maintenance expense by $24.2 million in the first quarter of 2015, resulting in after-tax earnings of $14.5 million. On May 5, 2015, NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers beginning July 1, 2015. On June 24, 2015, the DPU delayed the effective date of NSTAR Electric's proposed rate increase from July 1, 2015 to November 1, 2015 to allow for the DPU staff to review the reconciliations. NSTAR Electric requested recovery from customers effective January 1, 2016 in briefs filed with the DPU in October 2015. On October 27, 2015, the DPU delayed the effective date of the rate increase from November 1, 2015 to December 1, 2015 to allow the DPU staff additional time to review the reconciliations. NSTAR Electric expects a decision from the DPUin the fourth quarter of2015.

CL&P Distribution Rates: On July 2, 2015, PURA issued a final order that allows for an increase to rate base of approximately $163 million associated with ADIT, including a regulatory asset to recover the incremental revenue requirement for the period December 1, 2014 through November 30, 2015 over a subsequent two-year period. The rate base increase provided an increase to total allowed annual revenue requirements of $18.4 million beginning December 1, 2014. Of that amount, $15.3 million has been recorded as a regulatory asset through September 30, 2015, with a corresponding increase in Operating Revenues.

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CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Operating Revenues	$ 1,933,105	$ 1,892,532	$ 6,263,597	$ 5,860,736
Operating Expenses:
Purchased Power and Transmission	702,640	716,631	2,549,807	2,318,993
Operations and Maintenance	327,283	344,092	977,306	1,069,015
Depreciation	167,884	153,210	495,389	456,224
Amortization of Regulatory Assets/(Liabilities), Net	(16,851)	(22,531)	42,587	31,826
Energy Efficiency Programs	132,107	118,693	380,559	360,228
Taxes Other Than Income Taxes	150,804	141,527	439,221	421,862
Total Operating Expenses	1,463,867	1,451,622	4,884,869	4,658,148
Operating Income	469,238	440,910	1,378,728	1,202,588
Interest Expense:
Total Interest Expense	92,534	89,738	279,635	272,208
Other Income/(Loss), Net	5,241	11,860	23,866	19,054
Income Before Income Tax Expense	381,945	363,032	1,122,959	949,434
Income Tax Expense	144,146	126,539	420,640	345,858
Net Income	237,799	236,493	702,319	603,576
Net Income Attributable to Noncontrolling Interests	1,879	1,879	5,639	5,639
Net Income Attributable to Controlling Interests	$ 235,920	$ 234,614	$ 696,680	$ 597,937
Basic Earnings Per Common Share	$ 0.74	$ 0.74	$ 2.20	$ 1.89
Diluted Earnings Per Common Share	0.74	0.74	2.19	1.89
Common Stock Dividends Per Share Declared	$ 0.42	$ 0.39	$ 1.25	$ 1.18
Weighted Average Common Shares Outstanding:
Basic	317,452,212	316,340,691	317,296,107	315,941,904
Diluted	318,405,269	317,554,925	318,396,042	317,186,490
The Connecticut Light And Power Company [Member]
Operating Revenues	$ 704,262	$ 695,642	$ 2,175,733	$ 2,017,580
Operating Expenses:
Purchased Power and Transmission	274,762	255,787	861,562	736,952
Operations and Maintenance	122,280	127,285	358,324	368,562
Depreciation	54,809	46,886	159,903	139,598
Amortization of Regulatory Assets/(Liabilities), Net	(22,859)	13,098	17,917	62,644
Energy Efficiency Programs	42,590	41,399	119,360	119,389
Taxes Other Than Income Taxes	71,563	64,994	201,743	194,105
Total Operating Expenses	543,145	549,449	1,718,809	1,621,250
Operating Income	161,117	146,193	456,924	396,330
Interest Expense:
Total Interest Expense	36,716	38,735	109,463	110,448
Other Income/(Loss), Net	2,356	6,456	8,576	10,658
Income Before Income Tax Expense	126,757	113,914	356,037	296,540
Income Tax Expense	46,569	30,038	127,845	95,980
Net Income	80,188	83,876	228,192	200,560
NSTAR Electric Company [Member]
Operating Revenues	750,724	727,909	2,134,728	1,955,609
Operating Expenses:
Purchased Power and Transmission	299,040	317,784	984,035	879,773
Operations and Maintenance	83,486	79,705	228,740	244,610
Depreciation	49,101	47,455	146,818	140,996
Amortization of Regulatory Assets/(Liabilities), Net	2,257	(15,063)	(10,643)	(916)
Energy Efficiency Programs	67,693	56,915	164,843	145,499
Taxes Other Than Income Taxes	34,982	34,513	95,821	99,121
Total Operating Expenses	536,559	521,309	1,609,614	1,509,083
Operating Income	214,165	206,600	525,114	446,526
Interest Expense:
Total Interest Expense	18,992	17,338	57,218	59,091
Other Income/(Loss), Net	513	3,287	3,649	3,011
Income Before Income Tax Expense	195,686	192,549	471,545	390,446
Income Tax Expense	77,062	76,975	187,397	156,655
Net Income	118,624	115,574	284,148	233,791
Public Service Company Of New Hampshire [Member]
Operating Revenues	234,364	223,664	761,086	735,123
Operating Expenses:
Purchased Power and Transmission	53,017	64,397	200,533	247,992
Operations and Maintenance	65,190	65,563	200,085	198,025
Depreciation	26,592	24,568	77,989	73,247
Amortization of Regulatory Assets/(Liabilities), Net	1,967	(9,734)	29,148	(17,565)
Energy Efficiency Programs	3,873	3,766	11,001	10,897
Taxes Other Than Income Taxes	20,104	18,702	61,435	53,051
Total Operating Expenses	170,743	167,262	580,191	565,647
Operating Income	63,621	56,402	180,895	169,476
Interest Expense:
Total Interest Expense	11,647	11,024	34,582	33,995
Other Income/(Loss), Net	685	461	2,313	1,673
Income Before Income Tax Expense	52,659	45,839	148,626	137,154
Income Tax Expense	20,158	17,603	56,135	52,199
Net Income	32,501	28,236	92,491	84,955
Western Massachusetts Electric Company [Member]
Operating Revenues	125,093	118,145	403,151	363,843
Operating Expenses:
Purchased Power and Transmission	36,465	43,926	149,182	130,977
Operations and Maintenance	21,762	20,820	61,651	67,085
Depreciation	11,196	10,506	32,420	31,144
Amortization of Regulatory Assets/(Liabilities), Net	3,930	(8,519)	11,194	(7,778)
Energy Efficiency Programs	12,107	10,983	32,701	33,096
Taxes Other Than Income Taxes	9,599	9,200	28,430	25,679
Total Operating Expenses	95,059	86,916	315,578	280,203
Operating Income	30,034	31,229	87,573	83,640
Interest Expense:
Total Interest Expense	5,901	6,576	19,014	18,929
Other Income/(Loss), Net	587	502	2,406	1,670
Income Before Income Tax Expense	24,720	25,155	70,965	66,381
Income Tax Expense	9,749	10,490	28,555	26,596
Net Income	$ 14,971	$ 14,665	$ 42,410	$ 39,785

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COMMON SHARESHOLDERS' EQUITY AND NONCONTROLLING INTERESTS (NU)

3 Months Ended

Sep. 30, 2015

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 September 30, 2015 and 2014 and $5.6 million for the nine months ended September 30, 2015 and 2014. These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. 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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DOCUMENT AND ENTITY INFORMATION	9 Months Ended
	Sep. 30, 2015 USD ($) shares
Document And Entity [Line Items]
Entity Registrant Name	Eversource Energy
Document Period End Date	Sep. 30, 2015
Document Type	10-Q
Entity Central Index Key	0000072741
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding	317,191,249
Entity Public Float | $	$ 14,272,287,390
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	2015
Document Fiscal Period Focus	Q3
Amendment Flag	false
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

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EARNINGS PER SHARE

3 Months Ended

Sep. 30, 2015

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. For the three and nine months ended September 30, 2015, there were 5,894 and 1,965 antidilutive share awards excluded from the computation, respectively. For the three and nine months ended September 30, 2014, 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 Nine Months Ended
(Millions of Dollars, except share information)		September 30, 2015		September 30, 2014		September 30, 2015		September 30, 2014
Net Income Attributable to Common Shareholders		$	235.9	$	234.6	$	696.7	$	597.9
Weighted Average Common Shares Outstanding:
	Basic		317,452,212		316,340,691		317,296,107		315,941,904
	Dilutive Effect		953,057		1,214,234		1,099,935		1,244,586
	Diluted		318,405,269		317,554,925		318,396,042		317,186,490
Basic EPS		$	0.74	$	0.74	$	2.20	$	1.89
Diluted EPS		$	0.74	$	0.74	$	2.19	$	1.89

RSUs and performance shares are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. The dilutive effect of unvested RSUs and performance shares is calculated using the treasury stock method. Assumed proceeds of these units under the treasury stock method consist of the remaining compensation cost to be recognized and a theoretical tax benefit. The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the units (the difference between the market value of the average units outstanding for the period, using the average market price during the period, and the grant date market value).

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

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Net Income	$ 237,799	$ 236,493	$ 702,319	$ 603,576
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	526	509	1,544	1,528
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	(2,803)	(216)	(3,919)	242
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	764	1,042	2,838	4,089
Other Comprehensive Income (Loss), Net of Tax, Total	(1,513)	1,335	463	5,859
Comprehensive Income Attributable to Noncontrolling Interests	(1,879)	(1,879)	(5,639)	(5,639)
Comprehensive Income	234,407	235,949	697,143	603,796
The Connecticut Light And Power Company [Member]
Net Income	80,188	83,876	228,192	200,560
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	111	111	333	333
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	(98)	(7)	(137)	8
Other Comprehensive Income (Loss), Net of Tax, Total	13	104	196	341
Comprehensive Income	80,201	83,980	228,388	200,901
NSTAR Electric Company [Member]
Net Income	118,624	115,574	284,148	233,791
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	(2)		(184)
Other Comprehensive Income (Loss), Net of Tax, Total	(2)		(184)
Comprehensive Income	118,622	115,574	283,964	233,791
Public Service Company Of New Hampshire [Member]
Net Income	32,501	28,236	92,491	84,955
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	291	290	872	871
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	(169)	(13)	(236)	14
Other Comprehensive Income (Loss), Net of Tax, Total	122	277	636	885
Comprehensive Income	32,623	28,513	93,127	85,840
Western Massachusetts Electric Company [Member]
Net Income	14,971	14,665	42,410	39,785
Other Comprehensive Income Loss Net Of Tax Period Increase Decrease Abstract
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	101	85	270	254
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	(27)	(2)	(38)	2
Other Comprehensive Income (Loss), Net of Tax, Total	74	83	232	256
Comprehensive Income	$ 15,045	$ 14,748	$ 42,642	$ 40,041

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PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSIONS

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Pension and Other Postretirement Benefits Disclosure [Text Block]

7.Pension Benefits and Postretirement Benefits Other than Pensions

As of December 31, 2014, Eversource Service sponsored two defined benefit retirement plans that covered eligible employees, including employees of CL&P, NSTAR Electric, PSNH and WMECO. Effective January 1, 2015, the two pension plans were merged into one plan, sponsored by Eversource Service. As of December 31, 2014, Eversource Service also sponsored defined benefit postretirement plans that provide certain retiree benefits, primarily medical, dental and life insurance, to retiring employees that meet certain age and service eligibility requirements, including employees of CL&P, NSTAR Electric, PSNH and WMECO. Effective January 1, 2015, the postretirement plans were merged into one plan, sponsored by Eversource Service.

Terminated Vested Lump-Sum Payout Offer: In August, 2015, Eversource made a total lump-sum payout of $149.5 million, which reduced the projected benefit obligation and Pension Plan assets by a corresponding amount. Therefore, the lump-sum payment option had no impact on the net Accrued Pension Liability reflected on the Eversource, CL&P, PSNH and WMECO balance sheets as of September 30, 2015.

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 is included in Operations and Maintenance 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. Intercompany allocations are not included in the CL&P, NSTAR Electric, PSNH and WMECO net periodic benefit expense amounts.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 and the corresponding capitalized portion, as these amounts are cash settled on a short-term basis.

	Pension and SERP				Pension and SERP
Eversource	For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2015 (1)		September 30, 2014		September 30, 2015 (1)		September 30, 2014
Service Cost	$	22.7	$	19.1	$	68.7	$	60.7
Interest Cost		56.9		56.4		170.3		169.5
Expected Return on Plan Assets		(83.9)		(77.7)		(252.1)		(233.1)
Actuarial Loss		36.5		31.7		111.9		96.5
Prior Service Cost		0.9		1.1		2.7		3.3
Total Net Periodic Benefit Expense	$	33.1	$	30.6	$	101.5	$	96.9
Capitalized Pension Expense	$	9.8	$	8.3	$	31.3	$	26.7
	PBOP				PBOP
Eversource	For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2015 (1)		September 30, 2014		September 30, 2015 (1)		September 30, 2014
Service Cost	$	4.1	$	3.1	$	10.3	$	9.3
Interest Cost		11.8		12.4		30.4		37.1
Expected Return on Plan Assets		(16.9)		(15.8)		(43.2)		(47.4)
Actuarial Loss		1.7		3.0		4.5		9.1
Prior Service Credit		(0.1)		(0.7)		(0.3)		(2.1)
Total Net Periodic Benefit Expense	$	0.6	$	2.0	$	1.7	$	6.0
Capitalized PBOP Expense/(Income)	$	-	$	1.1	$	0.1	$	1.9

	Pension and SERP
	For the Three Months Ended September 30, 2015								For the Three Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH (1)		WMECO		CL&P		Electric		PSNH		WMECO
Service Cost	$	6.2	$	3.7	$	3.1	$	1.0	$	5.0	$	3.0	$	2.3	$	0.8
Interest Cost		12.9		10.0		6.1		2.6		12.5		10.3		5.7		2.5
Expected Return on Plan Assets		(19.8)		(17.5)		(10.1)		(4.7)		(18.7)		(15.7)		(9.3)		(4.4)
Actuarial Loss		8.0		8.7		2.9		1.6		8.2		5.9		2.8		1.7
Prior Service Cost		0.4		-		0.1		0.1		0.4		-		0.1		0.1
Total Net Periodic Benefit Expense	$	7.7	$	4.9	$	2.1	$	0.6	$	7.4	$	3.5	$	1.6	$	0.7
Intercompany Allocations	$	5.8	$	3.4	$	1.6	$	1.1	$	6.5	$	2.9	$	1.8	$	1.2
Capitalized Pension Expense	$	4.7	$	2.7	$	0.8	$	0.5	$	4.3	$	2.6	$	0.7	$	0.6
	Pension and SERP
	For the Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric		PSNH (1)		WMECO		CL&P		Electric		PSNH		WMECO
Service Cost	$	18.4	$	11.2	$	9.0	$	3.2	$	15.2	$	10.6	$	7.4	$	2.7
Interest Cost		38.4		30.2		18.1		7.8		38.1		31.0		18.0		7.8
Expected Return on Plan Assets		(59.1)		(52.5)		(30.3)		(14.2)		(56.7)		(47.3)		(28.8)		(13.5)
Actuarial Loss		24.2		27.0		8.8		4.8		25.5		17.6		8.9		5.2
Prior Service Cost		1.1		0.1		0.4		0.2		1.4		-		0.5		0.3
Total Net Periodic Benefit Expense	$	23.0	$	16.0	$	6.0	$	1.8	$	23.5	$	11.9	$	6.0	$	2.5
Intercompany Allocations	$	18.0	$	10.3	$	5.0	$	3.3	$	20.8	$	6.7	$	6.0	$	3.9
Capitalized Pension Expense	$	14.1	$	8.6	$	2.6	$	1.4	$	13.6	$	5.5	$	2.4	$	2.0

	PBOP
	For the Three Months Ended September 30, 2015								For the Three Months Ended September 30, 2014
			NSTAR								NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH (1)		WMECO	CL&P		Electric		PSNH		WMECO
Service Cost	$	0.5	$	1.3	$	0.3	$	0.1	$	0.6	$	0.8	$	0.3	$	0.1
Interest Cost		1.8		4.8		1.0		0.3		2.0		4.9		1.1		0.4
Expected Return on Plan Assets		(2.8)		(6.8)		(1.5)		(0.6)		(2.6)		(6.5)		(1.4)		(0.6)
Actuarial Loss/(Gain)		0.2		0.6		0.1		-		1.0		(0.1)		0.6		0.1
Prior Service Credit		-		(0.1)		-		-		-		(0.5)		-		-
Total Net Periodic Benefit Expense/(Income)	$	(0.3)	$	(0.2)	$	(0.1)	$	(0.2)	$	1.0	$	(1.4)	$	0.6	$	0.0
Intercompany Allocations	$	0.4	$	0.2	$	0.1	$	0.1	$	0.9	$	0.3	$	0.2	$	0.2
Capitalized PBOP Expense/(Income)	$	(0.1)	$	-	$	0.1	$	-	$	0.5	$	(0.5)	$	0.2	$	-
	PBOP
	For the Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
			NSTAR									NSTAR
(Millions of Dollars)	CL&P		Electric			PSNH (1)		WMECO	CL&P			Electric	PSNH		WMECO
Service Cost	$	1.6	$	4.0	$	1.0	$	0.3	$	1.7	$	2.3	$	1.0	$	0.3
Interest Cost		5.4		14.2		2.9		1.1		6.0		14.6		3.2		1.3
Expected Return on Plan Assets		(8.3)		(20.5)		(4.4)		(1.9)		(7.9)		(19.5)		(4.1)		(1.7)
Actuarial Loss/(Gain)		0.5		1.8		0.4		-		3.2		(0.4)		1.7		0.3
Prior Service Credit		-		(0.1)		-		-		-		(1.4)		-		-
Total Net Periodic Benefit Expense/(Income)	$	(0.8)	$	(0.6)	$	(0.1)	$	(0.5)	$	3.0	$	(4.4)	$	1.8	$	0.2
Intercompany Allocations	$	1.4	$	0.7	$	0.3	$	0.3	$	3.1	$	0.4	$	0.8	$	0.6
Capitalized PBOP Expense/(Income)	$	(0.2)	$	(0.1)	$	0.2	$	(0.1)	$	1.5	$	(1.5)	$	0.6	$	0.1
(1) Amounts exclude approximately $0.8 million and $2.4 million for the three and nine months ended September 30, 2015, respectively, that represented amounts included in other deferred debits.

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SHORT TERM AND LONG TERM DEBT

9 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Debt Disclosure

6.SHORT-TERM AND LONG-TERM DEBT

Credit Agreements and Commercial Paper Programs:On October 26, 2015, Eversource parent, CL&P, PSNH, WMECO, NSTAR Gas and Yankee Gas amended and restated their joint five-year $1.45 billion revolving credit facility and extended the termination date to September 4, 2020. The facility serves to backstop Eversource parent's $1.45 billion commercial paper program. The commercial paper program allows Eversource parent to issue commercial paper as a form of short-term debt. As of September 30, 2015 and December 31, 2014, Eversource parent had $757 million and approximately $1.1 billion, respectively, in short-term borrowings outstanding under the Eversource parent commercial paper program, leaving $693 million and $348.9 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively. The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.41 percent and 0.43 percent, respectively. As of September 30, 2015, there were intercompany loans from Eversource parent of $137.3 million to PSNH and $126.2 million to WMECO. As of December 31, 2014, there were intercompany loans from Eversource parent of $133.4 million to CL&P, $90.5 million to PSNH and $21.4 million to WMECO.

On October 26, 2015, NSTAR Electric amended and restated its five-year $450 million revolving credit facility and extended the termination date to September 4, 2020. The facility serves to backstop NSTAR Electric's $450 million commercial paper program. As of September 30, 2015 and December 31, 2014, NSTAR Electric had $258.5 million and $302 million, respectively, in short-term borrowings outstanding under its commercial paper program, leaving $191.5 million and $148 million of available borrowing capacity as of September 30, 2015 and December 31, 2014, respectively. The weighted-average interest rate on these borrowings as of September 30, 2015 and December 31, 2014 was 0.18 percent and 0.27 percent, respectively.

On June 16, 2015, the FERC granted authorization to allow CL&P and WMECO to incur total short-term borrowings up to a maximum of $600 million and $300 million, respectively, effective January 1, 2016 through December 31, 2017.

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

Long-Term Debt: On January 15, 2015, Eversource parent issued $150 million of 1.60 percent Series G Senior Notes, due to mature in 2018 and $300 million of 3.15 percent Series H Senior Notes, due to mature in 2025. The proceeds, net of issuance costs, were used to repay short-term borrowings outstanding under the Eversource parent commercial paper program. As the debt issuances refinanced short-term debt, the short-term debt was classified as Long-Term Debt as of December31, 2014.

On April 1, 2015, CL&P repaid at maturity the $100 million 5.00 percent2005 Series AFirst and Refunding Mortgage Bonds using short-term borrowings. On April 1, 2015, CL&P also redeemed the $62 million 1996A Series 1.55 percent PCRBs that were subject to mandatory tender, using short term borrowings.

On May 20, 2015, CL&P issued $300 million of 4.15 percent 2015 Series A First and Refunding Mortgage Bonds due to mature in 2045. The proceeds, net of issuance costs, were used to repay short-term borrowings.

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

On September 10, 2015, Yankee Gas issued $75 million of 3.35 percent 2015 Series M First Mortgage Bonds due to mature in 2025. The proceeds, net of issuance costs, were used to repay short-term borrowings.

Long-Term Debt Issuance Authorization: On April 3, 2015, the DPU authorized NSTAR Gas to issue up to $100 million in long-term debt for the period through December31, 2015.

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Supplemental Cash Flow Information (Tables)

3 Months Ended

Sep. 30, 2015

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 September 30, 2015		As of September 30, 2014
Eversource		$	160.7		128.9
CL&P			46.0		52.2
NSTAR Electric			31.2		18.1
PSNH			33.8		21.0
WMECO			15.5		10.0

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SEGMENT INFORMATION

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Segment Reporting Disclosure [Text Block]

14.SEGMENT INFORMATION

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

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

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

	For the Three Months Ended September 30, 2015
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	1,543.7	$	106.2	$	270.4	$	211.6	$	(198.8)	$	1,933.1
Depreciation and Amortization		(84.5)		(17.5)		(42.4)		(7.1)		0.5		(151.0)
Other Operating Expenses		(1,140.8)		(92.7)		(78.3)		(199.6)		198.5		(1,312.9)
Operating Income		318.4		(4.0)		149.7		4.9		0.2		469.2
Interest Expense		(47.4)		(9.2)		(25.9)		(11.2)		1.2		(92.5)
Other Income, Net		1.9		(0.2)		3.8		241.9		(242.2)		5.2
Net Income Attributable to Common Shareholders	$	167.5	$	(3.7)	$	78.0	$	234.9	$	(240.8)	$	235.9
	For the Nine Months Ended September 30, 2015
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	4,686.5	$	799.6	$	787.2	$	655.2	$	(664.9)	$	6,263.6
Depreciation and Amortization		(342.1)		(53.4)		(122.6)		(21.5)		1.6		(538.0)
Other Operating Expenses		(3,535.7)		(631.5)		(225.5)		(619.4)		665.2		(4,346.9)
Operating Income		808.7		114.7		439.1		14.3		1.9		1,378.7
Interest Expense		(140.6)		(27.2)		(79.8)		(35.4)		3.4		(279.6)
Other Income, Net		9.6		(0.1)		11.9		777.0		(774.5)		23.9
Net Income Attributable to Common Shareholders	$	418.9	$	57.3	$	225.0	$	764.7	$	(769.2)	$	696.7
Cash Flows Used for Investments in Plant	$	506.5	$	120.0	$	493.9	$	56.9	$	-	$	1,177.3

	For the Three Months Ended September 30, 2014
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	1,502.6	$	109.2	$	262.5	$	211.2	$	(193.0)	$	1,892.5
Depreciation and Amortization		(71.7)		(16.4)		(37.4)		(13.8)		8.6		(130.7)
Other Operating Expenses		(1,141.5)		(98.4)		(74.2)		(192.4)		185.6		(1,320.9)
Operating Income/(Loss)		289.4		(5.6)		150.9		5.0		1.2		440.9
Interest Expense		(49.2)		(8.5)		(24.5)		(8.6)		1.0		(89.8)
Other Income, Net		9.3		0.1		2.7		226.4		(226.6)		11.9
Net Income/Loss) Attributable to Common Shareholders	$	153.4	$	(9.9)	$	88.1	$	228.3	$	(225.3)	$	234.6
	For the Nine Months Ended September 30, 2014
Eversource	Electric		Natural Gas		Electric
(Millions of Dollars)	Distribution		Distribution		Transmission		Other		Eliminations		Total
Operating Revenues	$	4,350.4	$	737.5	$	721.4	$	568.1	$	(516.7)	$	5,860.7
Depreciation and Amortization		(309.9)		(51.1)		(111.4)		(28.3)		12.7		(488.0)
Other Operating Expenses		(3,343.9)		(586.2)		(211.5)		(534.1)		505.6		(4,170.1)
Operating Income		696.6		100.2		398.5		5.7		1.6		1,202.6
Interest Expense		(143.8)		(25.6)		(78.8)		(27.2)		3.2		(272.2)
Other Income, Net		13.6		0.2		6.9		657.9		(659.5)		19.1
Net Income Attributable to Common Shareholders	$	349.1	$	44.2	$	206.8	$	653.4	$	(655.6)	$	597.9
Cash Flows Used for Investments in Plant	$	480.1	$	120.6	$	469.9	$	46.9	$	-	$	1,117.5
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 September 30, 2015	$	17,836.8	$	2,986.0	$	7,773.7	$	12,750.0	$	(11,300.5)	$	30,046.0
As of December 31, 2014		17,563.4		3,030.9		7,625.6		12,682.5		(11,124.4)		29,778.0

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ACCUMULATED OTHER COMPREHENSIVE INCOME

3 Months Ended

Sep. 30, 2015

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 Nine Months Ended September 30, 2015								For the Nine Months Ended September 30, 2014
	Qualified		Unrealized						Qualified		Unrealized
	Cash Flow		Gains/(Losses)		Defined				Cash Flow		Gains on		Defined
Eversource	Hedging		on Marketable		Benefit				Hedging		Marketable		Benefit
(Millions of Dollars)	Instruments		Securities		Plans		Total		Instruments		Securities		Plans		Total
Balance as of Beginning of Period	$	(12.4)	$	0.7	$	(62.3)	$	(74.0)	$	(14.4)	$	0.4	$	(32.0)	$	(46.0)
OCI Before Reclassifications		-		(3.9)		(0.4)		(4.3)		-		0.2		1.2		1.4
Amounts Reclassified from AOCI		1.5		-		3.3		4.8		1.5		-		2.9		4.4
Net OCI		1.5		(3.9)		2.9		0.5		1.5		0.2		4.1		5.8
Balance as of End of Period	$	(10.9)	$	(3.2)	$	(59.4)	$	(73.5)	$	(12.9)	$	0.6	$	(27.9)	$	(40.2)

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, which are not material to their respective financial statements.The amortization expense of actuarial gains and losses on the defined benefit plans is amortized from AOCI into Operations and Maintenance over the average future employee service period, and is reflected in amounts reclassified from AOCI. The related tax effects of the reclassification adjustments are not material to the financial statements for the nine months ended September 30, 2015 and 2014.

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COMMITMENTS AND CONTINGENCIES

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Commitments and Contingencies Disclosure [Text Block]

8.       COMMITMENTS AND CONTINGENCIES

A.Environmental Matters

General: Eversource, CL&P, NSTAR Electric, PSNH and WMECO are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites. Eversource, CL&P, NSTAR Electric, PSNH and WMECO have an active environmental auditing and training program and believe that they are substantially in compliance with all enacted laws and regulations.

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

	As of September 30, 2015				As of December 31, 2014
			Reserve				Reserve
	Number of Sites		(in millions)		Number of Sites		(in millions)
Eversource		64	$	46.9		65	$	43.3
CL&P		14		4.8		16		3.8
NSTAR Electric		14		2.2		13		1.1
PSNH		12		3.4		13		5.2
WMECO		4		0.6		4		0.5

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. The reserve balance related to these former MGP sites was $41million and $38.8million as of September 30, 2015 and December31, 2014, respectively, and relates primarily to the natural gas business segment.

These estimates are subjective in nature as they take into consideration several different remediation options at each specific site. The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource, CL&P, NSTAR Electric, PSNH, or WMECO's responsibility or the extent of remediation required, recently enacted laws and regulations or a change in the estimates due to certain economic factors.

B.       Guarantees and Indemnifications

Eversource parentprovides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, in the form of guarantees in the normal course of business.

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

Eversource parentissued 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 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.

Eversourceparent has provided a guaranty of various indemnification and other obligationsas a result of the April 13, 2015 sale of substantially all of the assets of E.S. Boulos Company, an unregulated electrical contractor based in Maine and indirect subsidiary of Eversource Energy.Eversource parenthas also guaranteedcertain indemnification and other obligations as a result of the sales of former unregulated subsidiaries and the termination of an unregulated business, with maximum exposures either not specified or not material.

Management does not anticipate a material impact to Net Income as a result of these various guarantees and indemnifications.

The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries, including CL&P, NSTAR Electric, PSNH and WMECO, and guarantees to external parties, as of September 30, 2015:

			Maximum Exposure
Company		Description	(in millions)		Expiration Dates
On behalf of subsidiaries:
	Various	Surety Bonds (1)	$	33.2	2015 - 2016
	Eversource Service and Rocky River Realty Company	Lease Payments for Vehicles and Real Estate	$	12.2	2019 and 2024
On behalf of external parties:
	Purchaser of E.S. Boulos Company and a bonding company	E.S. Boulos Company Indemnification	$	38.2	2016 and 2020
	Algonquin Gas Transmission, LLC	Access Northeast project
	(owner of Access Northeast assets)	capital contributions guarantee	$	206.0		2021

(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 Eversourceare downgraded.

C.       FERC ROE Complaints

Three separate complaints have been filed at FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (the "Complainants"). In the first complaint, filed in 2011, the Complainants alleged that the NETOs' base ROE of 11.14 percent that had been utilized since 2006 was unjust and unreasonable, asserted that the rate was excessive due to changes in the capital markets, and sought an order to reduce it prospectively from the date of the final FERC order and for the 15-month period beginning October 1, 2011 to December 31, 2012 (the "first complaint refund period"). In the second and third complaints, filed in 2012 and 2014, the Complainants challenged the NETOs' base ROE and sought refunds for the respective 15-month periods beginning December27, 2012 and July 31, 2014.

In 2014, the FERC determined that the base ROE should be set at 10.57 percent for the first complaint refund period and that a utility's total or maximum ROE should not exceed the top of the new zone of reasonableness, which was set at 11.74 percent. The FERC ordered the NETOs to provide refunds to customers for the first complaint refund period and set the new base ROE of 10.57 percent prospectively from October16, 2014. The NETOs and the Complainants sought rehearing from FERC. In late 2014, the NETOs made a compliance filing, which was challenged by the Complainants, and the Company began refunding amounts from the first complaint period.

On March 3, 2015, FERC issued an order denying all issues raised on rehearing by the NETOs and Complainants in the first complaint. The FERC order upheld the base ROE of 10.57 percent for the first complaint refund period and prospectively from October 16, 2014, and upheld that the utility's total ROE (the base ROEplus anyincentive adders) for the transmission assets to which the adder applies is capped at the top of the zone of reasonableness, which is currently set at 11.74 percent. As a result of the clarifying information in the March 2015 order related to the application of the ROE cap, Eversource adjusted its reserve in the firstquarter 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 to the D.C. Circuit Court of Appeals, which have been consolidated, and briefing is scheduled to be concluded in the second quarter of 2016. A court decision is not expected until the second half of 2016.

For the second and third complaint proceedings, hearings were held in late June and early July 2015 and briefs were filed in July and August 2015. The state parties, municipal utilities and FERC trial staff each believe that the base ROE should be reduced. The NETOs believe that the Complainants' positions are without merit, and the existing ROEs should be maintained. The FERC ALJ's initial recommendation is expected by December 30, 2015, and a final FERC order is expected in the third quarter of 2016.

D.NSTAR Electric Basic Service Bad Debt Adder

On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006. As a result of the DPU order, NSTAR Electric increased its regulatory assets and reduced operations and maintenance expense by $24.2 million in the first quarter of 2015, resulting in after-tax earnings of $14.5 million. On May 5, 2015, NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers beginning July 1, 2015. On June 24, 2015, the DPU delayed the effective date of NSTAR Electric's proposed rate increase from July 1, 2015 to November 1, 2015 to allow for the DPU staff to review the reconciliations. NSTAR Electric requested recovery from customers effective January 1, 2016 in briefs filed with the DPU in October 2015.On October 27, 2015, the DPU delayed the effective date of the rate increase from November 1, 2015 to December 1, 2015 to allow the DPU staff additional time to review the reconciliations. NSTAR Electric expects a decision from the DPUin the fourth quarter of2015.

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

Upon completion of the divestiture process, all remaining stranded costs, including any remaining deferred equity return in excess of the $25 million that PSNH has agreed to forego, will be recovered via bonds that will be secured by a non-bypassable charge in rates billed to PSNH's customers.

Implementation of the Agreement is subject to NHPUC approval, which is expected in early 2016.

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FAIR VALUE OF FINANCIAL INSTRUMENTS

3 Months Ended

Sep. 30, 2015

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 September 30, 2015				As of December 31, 2014
Eversource	Carrying		Fair		Carrying		Fair
(Millions of Dollars)	Amount		Value		Amount		Value
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	157.3	$	155.6	$	153.6
Long-Term Debt		8,986.4		9,419.6		8,851.6		9,451.2

	As of September 30, 2015
	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
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	115.4	$	43.0	$	41.9	$	-	$	-	$	-	$	-
Long-Term Debt		2,975.3		3,285.1		1,792.7		1,931.3		1,076.3		1,135.5		577.8		613.3
	As of December 31, 2014
	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
Preferred Stock Not Subject to Mandatory Redemption	$	116.2	$	112.0	$	43.0	$	41.6	$	-	$	-	$	-	$	-
Long-Term Debt		2,842.0		3,214.5		1,797.4		1,993.5		1,076.3		1,137.9		628.5		689.4

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

Other Financial Instruments: Investments in marketable securities are carried at fair value. For further information, see Note5, "Marketable Securities," to the financial statements. The carrying value of other financial instruments included in current assets and current liabilities, including cash and cash equivalents and special deposits, approximates their fair value due to the short-term nature of these instruments.

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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COMMON SHARES

3 Months Ended

Sep. 30, 2015

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 and the respective per share par values:

	Shares
			Authorized as of
	Per Share		September 30, 2015 and	Issued as of
	Par Value		December 31, 2014	September 30, 2015	December 31, 2014
Eversource	$	5	380,000,000	333,862,615	333,359,172
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 September 30, 2015 and December31, 2014, there were 16,671,366 and 16,375,835 Eversource common shares held as treasury shares, respectively. As of September 30, 2015 and December31, 2014, Eversource common shares outstanding were 317,191,249 and 316,983,337, respectively. In May 2015, the Company repurchased 532,521 treasury shares at a share price of $47.94.

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EARNINGS PER SHARE (Tables)

3 Months Ended

Sep. 30, 2015

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 Nine Months Ended
(Millions of Dollars, except share information)		September 30, 2015		September 30, 2014		September 30, 2015		September 30, 2014
Net Income Attributable to Common Shareholders		$	235.9	$	234.6	$	696.7	$	597.9
Weighted Average Common Shares Outstanding:
	Basic		317,452,212		316,340,691		317,296,107		315,941,904
	Dilutive Effect		953,057		1,214,234		1,099,935		1,244,586
	Diluted		318,405,269		317,554,925		318,396,042		317,186,490
Basic EPS		$	0.74	$	0.74	$	2.20	$	1.89
Diluted EPS		$	0.74	$	0.74	$	2.19	$	1.89

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Other Contingencies (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2015
Loss Contingencies Line Items
Public Utilities Disclosure Of Regulatory Matters	2015 Regulatory Developments: FERC ROE Complaints: As a result of the March 3, 2015 FERC order in the pending ROE complaint proceedings described in Note 8C, "Commitments and Contingencies – FERC ROE Complaints," in 2015, Eversource recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO. The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues. NSTAR Electric and NSTAR Gas 2014 Comprehensive Settlement Agreement: On March 2, 2015, the DPU approved the comprehensive settlement agreement between NSTAR Electric, NSTAR Gas and the Massachusetts Attorney General (the "Settlement") as filed with the DPU on December 31, 2014. The Settlement resolved the outstanding NSTAR Electric CPSL program filings for 2006 through 2011, the NSTAR Electric and NSTAR Gas PAM and energy efficiency-related customer billing adjustments reported in 2012, and the recovery of LBR related to NSTAR Electric's energy efficiency programs for 2009 through 2011 (11 dockets in total). In 2015, as a result of the DPU order, NSTAR Electric and NSTAR Gas commenced refunding a combined $44.7 million to customers, which was recorded as a regulatory liability. NSTAR Electric recognized a $21.7 million pre-tax benefit in the first quarter of 2015 as a result of the approval of the Settlement. NSTAR Electric Basic Service Bad Debt Adder: On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006. As a result of the DPU order, NSTAR Electric increased its regulatory assets and reduced operations and maintenance expense by $24.2 million in the first quarter of 2015, resulting in after-tax earnings of $14.5 million. On May 5, 2015, NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers beginning July 1, 2015. On June 24, 2015, the DPU delayed the effective date of NSTAR Electric’s proposed rate increase from July 1, 2015 to November 1, 2015 to allow for the DPU staff to review the reconciliations. NSTAR Electric requested recovery from customers effective January 1, 2016 in briefs filed with the DPU in October 2015. On October 27, 2015, the DPU delayed the effective date of the rate increase from November 1, 2015 to December 1, 2015 to allow the DPU staff additional time to review the reconciliations. NSTAR Electric expects a decision from the DPU in the fourth quarter of 2015. CL&P Distribution Rates: On July 2, 2015, PURA issued a final order that allows for an increase to rate base of approximately $163 million associated with ADIT, including a regulatory asset to recover the incremental revenue requirement for the period December 1, 2014 through November 30, 2015 over a subsequent two-year period. The rate base increase provided an increase to total allowed annual revenue requirements of $18.4 million beginning December 1, 2014. Of that amount, $15.3 million has been recorded as a regulatory asset through September 30, 2015, with a corresponding increase in Operating Revenues.
FERC ROE Reserve - Incentive - First and Second Complaint [Member]
Loss Contingencies Line Items
Loss Contingency Loss in Period		$ 20.0
FERC ROE Reserve - Incentive - First and Second Complaint [Member] | The Connecticut Light And Power Company [Member]
Loss Contingencies Line Items
Loss Contingency Loss in Period		12.5
FERC ROE Reserve - Incentive - First and Second Complaint [Member] | NSTAR Electric Company [Member]
Loss Contingencies Line Items
Loss Contingency Loss in Period		2.4
FERC ROE Reserve - Incentive - First and Second Complaint [Member] | Public Service Company Of New Hampshire [Member]
Loss Contingencies Line Items
Loss Contingency Loss in Period		1.0
FERC ROE Reserve - Incentive - First and Second Complaint [Member] | Western Massachusetts Electric Company [Member]
Loss Contingencies Line Items
Loss Contingency Loss in Period		$ 4.1

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Provision for Uncollectible Accounts (Tables)

3 Months Ended

Sep. 30, 2015

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 September 30, 2015		As of December 31, 2014		As of September 30, 2015		As of December 31, 2014
Eversource	$	185.8	$	175.3	$	86.6	$	91.5
CL&P		79.5		84.3		64.9		74.0
NSTAR Electric		46.4		40.7		-		-
PSNH		9.4		7.7		-		-
WMECO		13.2		9.9		7.7		6.2

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DERIVATIVE INSTRUMENTS (Tables)

9 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

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

		As of September 30, 2015						As of December 31, 2014
		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 3:
	Eversource	$	16.6	$	(10.8)	$	5.8	$	16.2	$	(6.6)	$	9.6
	CL&P		16.6		(10.8)		5.8		16.1		(6.6)		9.5
	NSTAR Electric		-		-		-		0.1		-		0.1
Long-Term Derivative Assets:
Level 3:
	Eversource	$	67.7	$	(22.2)	$	45.5	$	93.5	$	(19.2)	$	74.3
	CL&P		65.6		(22.2)		43.4		93.5		(19.2)		74.3
	NSTAR Electric		2.1		-		2.1		-		-		-
Current Derivative Liabilities:
Level 2:
	Eversource	$	(4.6)	$	-	$	(4.6)	$	(9.8)	$	-	$	(9.8)
Level 3:
	Eversource		(92.6)		-		(92.6)		(90.0)		-		(90.0)
	CL&P		(91.4)		-		(91.4)		(88.5)		-		(88.5)
	NSTAR Electric		(1.2)		-		(1.2)		(1.5)		-		(1.5)
Long-Term Derivative Liabilities:
Level 2:
	Eversource	$	-	$	-	$	-	$	(0.3)	$	-	$	(0.3)
Level 3:
	Eversource		(365.7)		-		(365.7)		(409.3)		-		(409.3)
	CL&P		(364.7)		-		(364.7)		(406.2)		-		(406.2)
	NSTAR Electric		(1.0)		-		(1.0)		(3.1)		-		(3.1)

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

	For the Three Months Ended September 30,
	2015						2014
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(422.4)	$	(420.2)	$	(2.2)	$	(430.9)	$	(424.6)	$	(6.3)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities		(6.0)		(7.6)		1.6		(13.6)		(15.0)		1.4
Settlements		21.4		20.9		0.5		21.0		18.5		2.5
Fair Value as of End of Period	$	(407.0)	$	(406.9)	$	(0.1)	$	(423.5)	$	(421.1)	$	(2.4)
	For the Nine Months Ended September 30,
	2015						2014
					NSTAR						NSTAR
(Millions of Dollars)	Eversource		CL&P		Electric		Eversource		CL&P		Electric
Derivatives, Net:
Fair Value as of Beginning of Period	$	(415.4)	$	(410.9)	$	(4.5)	$	(635.2)	$	(630.6)	$	(7.3)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets and Liabilities		(55.3)		(56.6)		1.3		147.6		149.4		0.9
Settlements		63.7		60.6		3.1		64.1		60.1		4.0
Fair Value as of End of Period	$	(407.0)	$	(406.9)	$	(0.1)	$	(423.5)	$	(421.1)	$	(2.4)

Fairvalueinputsliabilitiesquantitativeinformationtabletextblock

	As of September 30, 2015						As of December 31, 2014
		Range				Period Covered		Range				Period Covered
Capacity Prices:
Eversource	$	10.30	-	13.13	per kW-Month	2016 - 2026	$	5.30	-	12.98	per kW-Month	2016 - 2026
CL&P	$	10.81	-	12.60	per kW-Month	2019 - 2026	$	11.08	-	12.98	per kW-Month	2018 - 2026
NSTAR Electric	$	10.30	-	13.13	per kW-Month	2016 - 2019	$	5.30	-	11.10	per kW-Month	2016 - 2019
Forward Reserve:
Eversource, CL&P	$	2.00			per kW-Month	2016 - 2024	$	5.80	-	9.50	per kW-Month	2015 - 2024
REC Prices:
Eversource, NSTAR Electric	$	45	-	50	per REC	2015 - 2018	$	38	-	56	per REC	2015 - 2018

XML

Environmental Matters (Details) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2015 USD ($)	Dec. 31, 2014 USD ($)
Site Contingency [Line Items]
Environmental Site Quantity	64	65
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 43.3
Ending Balance	46.9	$ 43.3
MGP Site accrual [Member]
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	38.8
Ending Balance	$ 41.0	$ 38.8
The Connecticut Light And Power Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	14	16
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 3.8
Ending Balance	$ 4.8	$ 3.8
NSTAR Electric Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	14	13
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 1.1
Ending Balance	$ 2.2	$ 1.1
Public Service Company Of New Hampshire [Member]
Site Contingency [Line Items]
Environmental Site Quantity	12	13
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 5.2
Ending Balance	$ 3.4	$ 5.2
Western Massachusetts Electric Company [Member]
Site Contingency [Line Items]
Environmental Site Quantity	4	4
Accrual for Environmental Loss Contingencies [Roll Forward]
Beginning Balance	$ 0.5
Ending Balance	$ 0.6	$ 0.5

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REGULATORY ACCOUNTING (Details) - USD ($) $ in Thousands	3 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Regulatory Asset [Line Items]
Regulatory Assets, Total	$ 4,605,700	$ 4,726,600
Regulatory Assets Current	653,892	672,493
Regulatory Assets Long Term	3,951,752	4,054,086
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	$ 59,400	60,500
Public Utilities Disclosure Of Regulatory Matters	2015 Regulatory Developments: FERC ROE Complaints: As a result of the March 3, 2015 FERC order in the pending ROE complaint proceedings described in Note 8C, "Commitments and Contingencies – FERC ROE Complaints," in 2015, Eversource recognized a pre-tax charge to earnings (excluding interest) of $20 million, of which $12.5 million was recorded at CL&P, $2.4 million at NSTAR Electric, $1 million at PSNH, and $4.1 million at WMECO. The pre-tax charge was recorded as a regulatory liability and as a reduction to Operating Revenues. NSTAR Electric and NSTAR Gas 2014 Comprehensive Settlement Agreement: On March 2, 2015, the DPU approved the comprehensive settlement agreement between NSTAR Electric, NSTAR Gas and the Massachusetts Attorney General (the "Settlement") as filed with the DPU on December 31, 2014. The Settlement resolved the outstanding NSTAR Electric CPSL program filings for 2006 through 2011, the NSTAR Electric and NSTAR Gas PAM and energy efficiency-related customer billing adjustments reported in 2012, and the recovery of LBR related to NSTAR Electric's energy efficiency programs for 2009 through 2011 (11 dockets in total). In 2015, as a result of the DPU order, NSTAR Electric and NSTAR Gas commenced refunding a combined $44.7 million to customers, which was recorded as a regulatory liability. NSTAR Electric recognized a $21.7 million pre-tax benefit in the first quarter of 2015 as a result of the approval of the Settlement. NSTAR Electric Basic Service Bad Debt Adder: On January 7, 2015, the DPU issued an order concluding that NSTAR Electric had removed energy-related bad debt costs from base distribution rates effective January 1, 2006. As a result of the DPU order, NSTAR Electric increased its regulatory assets and reduced operations and maintenance expense by $24.2 million in the first quarter of 2015, resulting in after-tax earnings of $14.5 million. On May 5, 2015, NSTAR Electric filed for recovery of the energy-related bad debt costs regulatory asset from customers beginning July 1, 2015. On June 24, 2015, the DPU delayed the effective date of NSTAR Electric’s proposed rate increase from July 1, 2015 to November 1, 2015 to allow for the DPU staff to review the reconciliations. NSTAR Electric requested recovery from customers effective January 1, 2016 in briefs filed with the DPU in October 2015. On October 27, 2015, the DPU delayed the effective date of the rate increase from November 1, 2015 to December 1, 2015 to allow the DPU staff additional time to review the reconciliations. NSTAR Electric expects a decision from the DPU in the fourth quarter of 2015. CL&P Distribution Rates: On July 2, 2015, PURA issued a final order that allows for an increase to rate base of approximately $163 million associated with ADIT, including a regulatory asset to recover the incremental revenue requirement for the period December 1, 2014 through November 30, 2015 over a subsequent two-year period. The rate base increase provided an increase to total allowed annual revenue requirements of $18.4 million beginning December 1, 2014. Of that amount, $15.3 million has been recorded as a regulatory asset through September 30, 2015, with a corresponding increase in Operating Revenues.
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	$ 743,700	750,100
Regulatory Liability Current	226,061	235,022
Regulatory Liabilities Long-Term	517,595	515,144
The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	1,664,300	1,695,800
Regulatory Assets Current	243,293	220,344
Regulatory Assets Long Term	1,420,974	1,475,508
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	2,400	1,300
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	213,300	206,000
Regulatory Liability Current	136,393	124,722
Regulatory Liabilities Long-Term	76,864	81,298
NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	1,403,500	1,377,800
Regulatory Assets Current	223,520	198,710
Regulatory Assets Long Term	1,179,996	1,179,100
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	21,100	33,200
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	279,600	312,300
Regulatory Liability Current	12,319	49,611
Regulatory Liabilities Long-Term	267,342	262,738
Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	361,900	404,800
Regulatory Assets Current	89,513	111,705
Regulatory Assets Long Term	272,360	293,115
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	3,200	900
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	61,000	67,400
Regulatory Liability Current	11,338	16,044
Regulatory Liabilities Long-Term	49,680	51,372
Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	182,500	198,200
Regulatory Assets Current	48,805	51,923
Regulatory Assets Long Term	133,697	146,307
Regulatory Assets And Liabilities Other Disclosures Abstract
Amount of Regulatory Costs Not yet Approved	16,200	11,000
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	36,200	33,300
Regulatory Liability Current	24,267	22,486
Regulatory Liabilities Long-Term	11,926	10,835
Cost Of Removal [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	433,700	439,900
Cost Of Removal [Member] | The Connecticut Light And Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	17,200	19,700
Cost Of Removal [Member] | NSTAR Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	257,700	258,300
Cost Of Removal [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	49,100	50,300
Cost Of Removal [Member] | Western Massachusetts Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	2,000	1,100
Regulatory Tracker Deferrals Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	215,900	192,300
Regulatory Tracker Deferrals Regulatory Liabilities [Member] | The Connecticut Light And Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	131,100	122,600
Regulatory Tracker Deferrals Regulatory Liabilities [Member] | NSTAR Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	13,000	20,700
Regulatory Tracker Deferrals Regulatory Liabilities [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	8,600	14,200
Regulatory Tracker Deferrals Regulatory Liabilities [Member] | Western Massachusetts Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	24,200	22,300
AFUDC Transmission Incentive [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	66,200	67,100
AFUDC Transmission Incentive [Member] | The Connecticut Light And Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	51,800	53,600
AFUDC Transmission Incentive [Member] | NSTAR Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	5,400	4,400
AFUDC Transmission Incentive [Member] | Western Massachusetts Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	9,000	9,100
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	27,900	50,800
Other Regulatory Liabilities [Member] | The Connecticut Light And Power Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	13,200	10,100
Other Regulatory Liabilities [Member] | NSTAR Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	3,500	28,900
Other Regulatory Liabilities [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	3,300	2,900
Other Regulatory Liabilities [Member] | Western Massachusetts Electric Company [Member]
Regulatory Liabilities [Line Items]
Regulatory Liabilities, Total	1,000	800
Benefit Costs [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	1,941,800	2,016,000
Benefit Costs [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	434,800	445,400
Benefit Costs [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	486,800	515,900
Benefit Costs [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	171,100	174,300
Benefit Costs [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	84,200	85,000
Regulatory Assets Offsetting Derivative Liabilities [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	412,800	425,500
Regulatory Assets Offsetting Derivative Liabilities [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	406,900	410,900
Regulatory Assets Offsetting Derivative Liabilities [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	1,400	4,500
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	635,800	635,300
Deferred Income Tax Charges Member | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	435,700	437,700
Deferred Income Tax Charges Member | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	83,500	83,700
Deferred Income Tax Charges Member | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	34,200	38,000
Deferred Income Tax Charges Member | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	30,500	35,500
Storm Restoration Costs [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	461,300	502,800
Storm Restoration Costs [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	286,500	319,600
Storm Restoration Costs [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	113,500	103,700
Storm Restoration Costs [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	36,300	47,700
Storm Restoration Costs [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	25,000	31,800
Goodwill Regulatory Asset [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	490,000	505,400
Goodwill Regulatory Asset [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	420,700	433,900
Regulatory Tracker Deferrals Regulatory Assets [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	373,100	350,500
Regulatory Tracker Deferrals Regulatory Assets [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	16,000	16,100
Regulatory Tracker Deferrals Regulatory Assets [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	228,000	141,400
Regulatory Tracker Deferrals Regulatory Assets [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	85,400	103,500
Regulatory Tracker Deferrals Regulatory Assets [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	30,100	33,000
Unrecovered Contractual Obligations [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	142,000	123,800
Other Regulatory Assets [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	148,900	167,300
Other Regulatory Assets [Member] | The Connecticut Light And Power Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	84,400	66,100
Other Regulatory Assets [Member] | NSTAR Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	69,600	94,700
Other Regulatory Assets [Member] | Public Service Company Of New Hampshire [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	34,900	41,300
Other Regulatory Assets [Member] | Western Massachusetts Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets, Total	$ 12,700	$ 12,900

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CONSOLIDATED STATEMENT OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Operating Activities:
Net Income	$ 702,319	$ 603,576
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	495,389	456,224
Deferred Income Tax Expense (Benefit)	153,353	64,755
Pension, SERP and PBOP Expense	71,802	74,296
Pension and PBOP Contributions	(162,880)	(74,681)
Regulatory Over/(Under) Recoveries, Net	31,874	290,111
Amortization of Regulatory Assets/(Liabilities), Net	42,587	31,826
Proceeds from DOE Damages Claim, Net	0	132,138
Other	(49,548)	(17,096)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(148,442)	(66,463)
Increase Decrease in Fuel, Materials and Supplies	47,380	(27,147)
Taxes Receivable/(Accrued)	383,047	26,533
Accounts Payable	(233,660)	(69,448)
Other Current Assets and Liabilities, Net	8,370	(20,607)
Net Cash Flows Provided by Operating Activities	1,341,591	1,404,017
Investing Activities:
Investments in Property, Plant and Equipment	(1,177,285)	(1,117,493)
Proceeds from Sales of Marketable Securities	556,582	388,352
Purchases of Marketable Securities	(535,044)	(389,406)
Other Investing Activities	(2,769)	(4,669)
Net Cash Flows Used in Investing Activities	(1,158,516)	(1,123,216)
Financing Activities:
Cash Dividends on Common Stock	(397,363)	(356,080)
Cash Dividends on Preferred Stock	(5,639)	(5,639)
Increase/(Decrease) in Short-Term Debt	(387,575)	6,000
Issuance of Long-Term Debt	825,000	650,000
Retirements of Long-Term Debt	(216,700)	(576,650)
Other Financing Activities	(3,720)	(90)
Net Cash Flows Provided by/(Used in) Financing Activities	(185,997)	(282,459)
Net Increase/(Decrease) in Cash	(2,922)	(1,658)
Cash - Beginning of Year	38,703	43,364
Cash - End of Year	35,781	41,706
The Connecticut Light And Power Company [Member]
Operating Activities:
Net Income	228,192	200,560
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	159,903	139,598
Deferred Income Tax Expense (Benefit)	(11,011)	(14,400)
Pension, SERP and PBOP Expense, Net of Contributions	10,654	8,050
Regulatory Over/(Under) Recoveries, Net	12,504	62,929
Amortization of Regulatory Assets/(Liabilities), Net	17,917	62,644
Proceeds from DOE Damages Claim		68,610
Other	(13,048)	(11,290)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(91,842)	(87,922)
Taxes Receivable/(Accrued)	160,031	39,805
Accounts Payable	(20,485)	16,984
Other Current Assets and Liabilities, Net	(31,044)	(2,575)
Net Cash Flows Provided by Operating Activities	421,771	482,993
Investing Activities:
Investments in Property, Plant and Equipment	(359,339)	(371,660)
Other Investing Activities	(740)	(4,539)
Net Cash Flows Used in Investing Activities	(360,079)	(376,199)
Financing Activities:
Cash Dividends on Common Stock	(147,000)	(128,400)
Cash Dividends on Preferred Stock	(4,169)	(4,169)
Issuance of Long-Term Debt	300,000	250,000
Increase/(Decrease) in Notes Payable to Affiliate	(133,400)	(181,900)
Retirements of Long-Term Debt	(162,000)	(150,000)
Capital Contributions from NU Parent	105,000	120,000
Other Financing Activities	(9,072)	(3,268)
Net Cash Flows Provided by/(Used in) Financing Activities	(50,641)	(97,737)
Net Increase/(Decrease) in Cash	11,051	9,057
Cash - Beginning of Year	2,356	7,237
Cash - End of Year	13,407	16,294
NSTAR Electric Company [Member]
Operating Activities:
Net Income	284,148	233,791
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	146,818	140,996
Deferred Income Tax Expense (Benefit)	54,188	(39,399)
Pension, SERP and PBOP Expense, Net of Contributions	(1,138)	(11,046)
Regulatory Over/(Under) Recoveries, Net	(48,903)	155,357
Amortization of Regulatory Assets/(Liabilities), Net	(10,643)	(916)
Proceeds from DOE Damages Claim		30,193
Other	(34,223)	(41,601)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(107,711)	(47,770)
Increase Decrease in Fuel, Materials and Supplies	21,863	(20,837)
Taxes Receivable/(Accrued)	207,516	60,252
Accounts Payable	(41,447)	(40,594)
Accounts Payable Related Parties	(14,878)	66,758
Other Current Assets and Liabilities, Net	46,671	32,340
Net Cash Flows Provided by Operating Activities	502,261	517,524
Investing Activities:
Investments in Property, Plant and Equipment	(314,055)	(309,248)
Net Cash Flows Used in Investing Activities	(314,055)	(309,248)
Financing Activities:
Cash Dividends on Common Stock	(148,500)	(253,000)
Cash Dividends on Preferred Stock	(1,470)	(1,470)
Increase/(Decrease) in Short-Term Debt	(43,500)	56,000
Issuance of Long-Term Debt	0	300,000
Retirements of Long-Term Debt	(4,700)	(301,650)
Other Financing Activities	0	(5,137)
Net Cash Flows Provided by/(Used in) Financing Activities	(198,170)	(205,257)
Net Increase/(Decrease) in Cash	(9,964)	3,019
Cash - Beginning of Year	12,773	8,021
Cash - End of Year	2,809	11,040
Public Service Company Of New Hampshire [Member]
Operating Activities:
Net Income	92,491	84,955
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	77,989	73,247
Deferred Income Tax Expense (Benefit)	42,563	67,827
Regulatory Over/(Under) Recoveries, Net	2,639	16,813
Amortization of Regulatory Assets/(Liabilities), Net	29,148	(17,565)
Proceeds from DOE Damages Claim		14,453
Other	10,894	10,834
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(25,126)	(7,467)
Increase Decrease in Fuel, Materials and Supplies	4,156	(17,350)
Taxes Receivable/(Accrued)	9,026	(24,108)
Accounts Payable	(20,058)	(9,297)
Other Current Assets and Liabilities, Net	20,141	13,470
Net Cash Flows Provided by Operating Activities	243,863	205,812
Investing Activities:
Investments in Property, Plant and Equipment	(209,522)	(170,127)
Other Investing Activities	241	(148)
Net Cash Flows Used in Investing Activities	(209,281)	(170,275)
Financing Activities:
Cash Dividends on Common Stock	(79,500)	(49,500)
Increase/(Decrease) in Notes Payable to Affiliate	46,800	66,800
Retirements of Long-Term Debt		(50,000)
Other Financing Activities	(268)	(217)
Net Cash Flows Provided by/(Used in) Financing Activities	(32,968)	(32,917)
Net Increase/(Decrease) in Cash	1,614	2,620
Cash - Beginning of Year	489	130
Cash - End of Year	2,103	2,750
Western Massachusetts Electric Company [Member]
Operating Activities:
Net Income	42,410	39,785
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	32,420	31,144
Deferred Income Tax Expense (Benefit)	5,531	13,479
Regulatory Over/(Under) Recoveries, Net	4,024	33,630
Amortization of Regulatory Assets/(Liabilities), Net	11,194	(7,778)
Proceeds from DOE Damages Claim		18,883
Other	(4,500)	615
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(32,664)	36,075
Taxes Receivable/(Accrued)	24,064	(15,831)
Accounts Payable	(14,018)	(12,847)
Other Current Assets and Liabilities, Net	(463)	(16,551)
Net Cash Flows Provided by Operating Activities	67,998	120,604
Investing Activities:
Investments in Property, Plant and Equipment	(93,705)	(82,546)
Proceeds from Sales of Marketable Securities	71,110	58,788
Purchases of Marketable Securities	(71,625)	(59,280)
Net Cash Flows Used in Investing Activities	(94,220)	(83,038)
Financing Activities:
Cash Dividends on Common Stock	(27,900)	(49,000)
Increase/(Decrease) in Notes Payable to Affiliate	104,800	13,200
Retirements of Long-Term Debt	50,000
Other Financing Activities	(20)	(29)
Net Cash Flows Provided by/(Used in) Financing Activities	26,880	(35,829)
Net Increase/(Decrease) in Cash	658	1,737
Cash - Beginning of Year	0	0
Cash - End of Year	$ 658	$ 1,737

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MARKETABLE SECURITIES

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Marketable Securities [Text Block]

5.       MARKETABLE SECURITIES

Eversource maintains trusts to fund certain non-qualified executive benefits and WMECO maintains a spent nuclear fuel trust to fund WMECO's prior period spent nuclear fuel liability. These trusts hold marketable securities.These trusts are not subject to regulatory oversight by state or federal agencies. In addition, CYAPC and YAEC maintain legally restricted trusts, each of which holds marketable securities, for paying the decommissioning and 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 September 30, 2015 and December 31, 2014, these securities were classified as Level 1 in the fair value hierarchy and totaled $14.2million and $85.1 million, respectively.Net losses on these securities of $0.5million and$1.9million for the three months ended September 30, 2015 and 2014, respectively, and net gains of $1.6million and $1.9 million, respectively, for the nine months ended September 30, 2015 and 2014, respectively,were recorded in Other Income, Net on the statements of income.Dividend income is recorded in Other Income, Net when dividends are declared. In 2015, certain of the securities classified as trading securities were sold and the proceeds were re-invested in equity securities designated as available-for-sale securities.

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

		As of September 30, 2015								As of December 31, 2014
				Pre-Tax		Pre-Tax						Pre-Tax		Pre-Tax
		Amortized		Unrealized		Unrealized				Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains		Losses		Fair Value		Cost		Gains		Losses		Fair Value
Eversource
	Debt Securities (1) (2)	$	311.6	$	3.6	$	(0.8)	$	314.4	$	313.0	$	7.5	$	(0.3)	$	320.2
	Equity Securities (1)		220.0		53.9		(6.0)		267.9		160.6		73.3		-		233.9
WMECO
	Debt Securities (2)		58.3		-		-		58.3		58.2		-		(0.1)		58.1

• Amounts include CYAPC's and YAEC's marketable securities held in nuclear decommissioning trusts of $430.2million and $450.8 million as of September 30, 2015 and December 31, 2014, respectively, which are legally restricted and can only be used for the costs of decommissioning and fuel removal of the nuclear fuel storage facilities owned by these companies. Unrealized gains and losses for the nuclear decommissioning trusts are recorded in Marketable Securities with the corresponding offset to Other Long-Term Liabilities on the balance sheets, with no impact on the statements of income.
• Unrealized gains and losses on debt securities held by WMECO are recorded in Marketable Securities with the corresponding offset to Other Long-Term Assets on the balance sheets.

Unrealized Losses and Other-than-Temporary Impairment: There have been no significant unrealized losses, other-than-temporary impairments or credit losses for Eversource or WMECO. 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, Other Long-Term Assets for WMECO, 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 WMECO trust and the CYAPC and YAEC nuclear decommissioning trusts to compute the realized gains and losses on the sale of available-for-sale securities.

Contractual Maturities: As of September 30, 2015, the contractual maturities of available-for-sale debt securities were as follows:

	Eversource				WMECO
	Amortized				Amortized
(Millions of Dollars)	Cost		Fair Value		Cost		Fair Value
Less than one year (1)	$	68.1	$	68.1	$	40.5	$	40.5
One to five years		67.6		68.0		14.2		14.2
Six to ten years		56.9		56.9		0.5		0.5
Greater than ten years		119.0		121.4		3.1		3.1
Total Debt Securities	$	311.6	$	314.4	$	58.3	$	58.3

1)Amounts in the Less than one year Eversource 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				WMECO
(Millions of Dollars)		As of September 30, 2015		As of December 31, 2014		As of September 30, 2015		As of December 31, 2014
Level 1:
	Mutual Funds and Equities	$	282.1	$	319.0	$	-	$	-
	Money Market Funds		30.7		24.9		8.0		4.3
Total Level 1		$	312.8	$	343.9	$	8.0	$	4.3
Level 2:
	U.S. Government Issued Debt Securities (Agency and Treasury)	$	41.3	$	51.3	$	-	$	-
	Corporate Debt Securities		57.5		49.1		12.2		14.7
	Asset-Backed Debt Securities		27.9		54.1		7.6		14.5
	Municipal Bonds		123.9		116.3		10.3		13.0
	Other Fixed Income Securities		33.1		24.5		20.2		11.6
Total Level 2		$	283.7	$	295.3	$	50.3	$	53.8
Total Marketable Securities		$	596.5	$	639.2	$	58.3	$	58.1

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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MARKETABLE SECURITIES (Tables)

3 Months Ended

Sep. 30, 2015

Notes To Consolidated Financial Statements [Abstract]

Schedule Of Available For Sale Securities Reconciliation [Table TextBlock]

		As of September 30, 2015								As of December 31, 2014
				Pre-Tax		Pre-Tax						Pre-Tax		Pre-Tax
		Amortized		Unrealized		Unrealized				Amortized		Unrealized		Unrealized
(Millions of Dollars)		Cost		Gains		Losses		Fair Value		Cost		Gains		Losses		Fair Value
Eversource
	Debt Securities (1) (2)	$	311.6	$	3.6	$	(0.8)	$	314.4	$	313.0	$	7.5	$	(0.3)	$	320.2
	Equity Securities (1)		220.0		53.9		(6.0)		267.9		160.6		73.3		-		233.9
WMECO
	Debt Securities (2)		58.3		-		-		58.3		58.2		-		(0.1)		58.1

Investments Classified by Contractual Maturity Date [Table Text Block]

	Eversource				WMECO
	Amortized				Amortized
(Millions of Dollars)	Cost		Fair Value		Cost		Fair Value
Less than one year (1)	$	68.1	$	68.1	$	40.5	$	40.5
One to five years		67.6		68.0		14.2		14.2
Six to ten years		56.9		56.9		0.5		0.5
Greater than ten years		119.0		121.4		3.1		3.1
Total Debt Securities	$	311.6	$	314.4	$	58.3	$	58.3

Fair Value Heirarchy [Table Text Block]

		Eversource				WMECO
(Millions of Dollars)		As of September 30, 2015		As of December 31, 2014		As of September 30, 2015		As of December 31, 2014
Level 1:
	Mutual Funds and Equities	$	282.1	$	319.0	$	-	$	-
	Money Market Funds		30.7		24.9		8.0		4.3
Total Level 1		$	312.8	$	343.9	$	8.0	$	4.3
Level 2:
	U.S. Government Issued Debt Securities (Agency and Treasury)	$	41.3	$	51.3	$	-	$	-
	Corporate Debt Securities		57.5		49.1		12.2		14.7
	Asset-Backed Debt Securities		27.9		54.1		7.6		14.5
	Municipal Bonds		123.9		116.3		10.3		13.0
	Other Fixed Income Securities		33.1		24.5		20.2		11.6
Total Level 2		$	283.7	$	295.3	$	50.3	$	53.8
Total Marketable Securities		$	596.5	$	639.2	$	58.3	$	58.1

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Other Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Excise And Sales Taxes	$ 37.8	$ 35.0	$ 112.9	$ 114.6
The Connecticut Light And Power Company [Member]
Excise And Sales Taxes	$ 35.5	$ 32.5	$ 98.0	$ 99.0

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SIGNIFCANT ACCOUNTING POLICIES (Policies)

3 Months Ended

Sep. 30, 2015

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.

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

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 entirety of this combined Quarterly Report on Form 10-Q, the first and second quarter 2015 combined Quarterly Report on Form 10-Qand the 2014 combined Annual Report on Form 10-K of Eversource, CL&P, NSTAR Electric, PSNH and WMECO, which were 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 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 September 30, 2015 and December31, 2014, the results of operations andcomprehensive income for the three and nine months ended September 30, 2015 and 2014, and the cash flows for the nine months ended September 30, 2015 and 2014. The results of operations and comprehensive incomefor the three and nine months ended September 30, 2015 and 2014 and the cash flows for the nine months ended September 30, 2015 and 2014 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.

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 accompanyingfinancial statements to conform to the current period presentation.

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 accounts are terminated and these balances are deemed to be uncollectible.

Derivatives Offsetting Fair Value Amounts Policy

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.

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 and nonrecurring fair value measurements of nonfinancial assets such as goodwill and AROs, and is also used to estimate the 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 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 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 payments in Taxes Other Than Income Taxes on the statements of income Certain sales taxes are collected by Eversource's companies that serve customers in Connecticut and Massachusetts as agents for state and local governments and 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 consider 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 that 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.

Derivatives Policy Text Block

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.

Marketable Securities Policy

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.

Environmental Costs Policy

Environmental Matters

General: Eversource, CL&P, NSTAR Electric, PSNH and WMECO are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites. Eversource, CL&P, NSTAR Electric, PSNH and WMECO have an active environmental auditing and training program and believe that they are substantially in compliance with all enacted laws and regulations.

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.

RSUs and performance shares are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. The dilutive effect of unvested RSUs and performance shares is calculated using the treasury stock method. Assumed proceeds of these units under the treasury stock method consist of the remaining compensation cost to be recognized and a theoretical tax benefit. The theoretical tax benefit is calculated as the tax impact of the intrinsic value of the units (the difference between the market value of the average units outstanding for the period, using the average market price during the period, and the grant date market value).

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

Segment Reporting Policy Policy Text Block

SEGMENT INFORMATION

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

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

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