0000072741 es:TheConnecticutLightAndPowerCompanyMember us-gaap:~~AccumulatedDefinedBenefitPlansAdjustmentMember~~OtherPostretirementBenefitPlansDefinedBenefitMember 2019-07-01 2019-09-30




	UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549
	FORM	10-Q
☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the Quarterly Period Ended	September 30, ~~2019~~2020
	or
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from ____________ to ____________

Registrant; State of Incorporation; Address; Telephone Number;

Commission File Number; and I.R.S. Employer Identification No.

EVERSOURCE ENERGY

(a Massachusetts voluntary association)

300 Cadwell Drive, Springfield, Massachusetts 01104

Telephone: (800) 286-5000

Commission File Number: 1-5324

I.R.S. Employer Identification No. 04-2147929

THE CONNECTICUT LIGHT AND POWER COMPANY

(a Connecticut corporation)

107 Selden Street, Berlin, Connecticut 06037-1616

Telephone: (800) 286-5000

Commission File Number: 0-00404

I.R.S. Employer Identification No. 06-0303850

NSTAR ELECTRIC COMPANY

(a Massachusetts corporation)

800 Boylston Street, Boston, Massachusetts 02199

Telephone: (800) 286-5000

Commission File Number: 1-02301

I.R.S. Employer Identification No. 04-1278810

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE

(a New Hampshire corporation)

Energy Park

780 North Commercial Street, Manchester, New Hampshire 03101-1134

Telephone: (800) 286-5000

Commission File Number: 1-6392

I.R.S. Employer Identification No. 02-0181050



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

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Shares, $5.00 par value per share	ES	New York Stock Exchange

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
	☒	☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files).



	Yes	No
	☒	☐

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



Eversource Energy	Large accelerated filer	☒	Accelerated filer	☐	Non-accelerated filer	☐	Smaller reporting company	☐	Emerging growth company	☐
The Connecticut Light and Power Company	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
NSTAR Electric Company	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐
Public Service Company of New Hampshire	Large accelerated filer	☐	Accelerated filer	☐	Non-accelerated filer	☒	Smaller reporting company	☐	Emerging growth company	☐

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

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



	Yes	No

Eversource Energy	☐	☒
The Connecticut Light and Power Company	☐	☒
NSTAR Electric Company	☐	☒
Public Service Company of New Hampshire	☐	☒

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



Company - Class of Stock	Outstanding as of October 31, ~~2019~~2020

Eversource Energy Common Shares, $5.00 par value	~~323,761,393~~342,824,425	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	200	shares
Public Service Company of New Hampshire Common Stock, $1.00 par value	301	shares

Eversource Energy holds all of the 6,035,205 shares, 200 shares, and 301 shares of the outstanding common stock of The Connecticut Light and Power Company, NSTAR Electric Company, and Public Service Company of New Hampshire, respectively.

NSTAR Electric Company and Public Service Company of New Hampshire 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, and Public Service Company of New Hampshire 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 and 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, Eversource Water Ventures, Inc. (parent company of Aquarion), and other subsidiaries, which primarily includes our unregulated businesses, HWP Company, The Rocky River Realty Company (a real estate subsidiary), the consolidated operations of CYAPC and YAEC, and Eversource parent's equity ownership interests that are not consolidated
CL&P	The Connecticut Light and Power Company
NSTAR Electric	NSTAR Electric Company
PSNH	Public Service Company of New Hampshire
PSNH Funding	PSNH Funding LLC 3, a bankruptcy remote, special purpose, wholly-owned subsidiary of PSNH
NSTAR Gas	NSTAR Gas Company
Yankee Gas	Yankee Gas Services Company
Aquarion	Eversource Aquarion Holdings, Inc. and its subsidiaries
NPT	Northern Pass Transmission LLC
Northern Pass	The HVDC and associated alternating-current transmission line project from Canada into New Hampshire
HEEC	Harbor Electric Energy Company, a wholly-owned subsidiary of NSTAR Electric
Eversource Service	Eversource Energy Service Company
Bay State Wind	Bay State Wind LLC, an offshore wind business being developed jointly by Eversource and Denmark-based Ørsted, which holds the Sunrise Wind project
North East Offshore	North East Offshore, LLC, an offshore wind business holding company being developed jointly by Eversource and Denmark-based Ørsted, which holds the Revolution Wind and South Fork Wind projects
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 and PSNH, the natural gas distribution businesses of Yankee Gas and NSTAR Gas, NPT, Aquarion, and the solar power facilities of NSTAR Electric
Regulators:
DEEP	Connecticut Department of Energy and Environmental Protection
DOE	U.S. Department of Energy
DOER	Massachusetts Department of Energy Resources
DPU	Massachusetts Department of Public Utilities
EPA	U.S. Environmental Protection Agency
FERC	Federal Energy Regulatory Commission
ISO-NE	ISO New England, Inc., the New England Independent System Operator
MA DEP	Massachusetts Department of Environmental Protection
NHPUC	New Hampshire Public Utilities Commission
PURA	Connecticut Public Utilities Regulatory Authority
SEC	U.S. Securities and Exchange Commission
SJC	Supreme Judicial Court of Massachusetts
Other Terms and Abbreviations:
ADIT	Accumulated Deferred Income Taxes
AFUDC	Allowance For Funds Used During Construction
AOCI	Accumulated Other Comprehensive Income
ARO	Asset Retirement Obligation
Bcf	Billion cubic feet
C&LM	Conservation and Load Management
CfD	Contract for Differences
CTA	Competitive Transition Assessment
CWIP	Construction Work in Progress
EDC	Electric distribution company
EDIT	Excess Deferred Income Taxes
EPS	Earnings Per Share
ERISA	Employee Retirement Income Security Act of 1974



ESOP	Employee Stock Ownership Plan
Eversource ~~2018~~2019 Form 10-K	The Eversource Energy and Subsidiaries ~~2018~~2019 combined Annual Report on Form 10-K as filed with the SEC
Fitch	Fitch Ratings
FMCC	Federally Mandated Congestion Charge
FTR	Financial Transmission Rights
GAAP	Accounting principles generally accepted in the United States of America
GSC	Generation Service Charge
GSRP	Greater Springfield Reliability Project
GWh	Gigawatt-Hours
HQ	Hydro-Québec, a corporation wholly-owned by the Québec government, including its divisions that produce, transmit and distribute electricity in Québec, Canada
HVDC	High-voltage direct current
Hydro Renewable Energy	Hydro Renewable Energy, Inc., a wholly-owned subsidiary of Hydro-Québec
IPP	Independent Power Producers
ISO-NE Tariff	ISO-NE FERC Transmission, Markets and Services Tariff
kV	Kilovolt
kVa	Kilovolt-ampere
kW	Kilowatt (equal to one thousand watts)
LBR	Lost Base Revenue
LNG	Liquefied natural gas
LRS	Supplier of last resort service
MG	Million gallons
MGP	Manufactured Gas Plant
MMBtu	One million British thermal units
MMcf	Million cubic feet
Moody's	Moody's Investors Services, Inc.
MW	Megawatt
MWh	Megawatt-Hours
NEEWS	New England East-West Solution
NETOs	New England Transmission Owners (including Eversource, National Grid and Avangrid)
OCI	Other Comprehensive Income/(Loss)
PAM	Pension and PBOP Rate Adjustment Mechanism
PBOP	Postretirement Benefits Other Than Pension
PBOP Plan	Postretirement Benefits Other Than Pension Plan
~~PCRBs~~	~~Pollution Control Revenue Bonds~~
Pension Plan	Single uniform noncontributory defined benefit retirement plan
PPA	~~Pension Protection Act~~Power purchase agreement
RECs	Renewable Energy Certificates
Regulatory ROE	The average cost of capital method for calculating the return on equity related to the distribution business segment excluding the wholesale transmission segment
ROE	Return on Equity
RRBs	Rate Reduction Bonds or Rate Reduction Certificates
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
SS	Standard service
TCAM	Transmission Cost Adjustment Mechanism
TSA	Transmission Service Agreement
UI	The United Illuminating Company
VIE	Variable Interest Entity

EVERSOURCE ENERGY AND SUBSIDIARIES

THE CONNECTICUT LIGHT AND POWER COMPANY

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

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 Common Shareholders' Equity	3
	Condensed Consolidated Statements of Cash Flows	45

	The Connecticut Light and Power Company (Unaudited)
	Condensed Balance Sheets	56
	Condensed Statements of Income	67
	Condensed Statements of Comprehensive Income	67
	Condensed Statements of Common Stockholder's Equity	78
	Condensed Statements of Cash Flows	89

	NSTAR Electric Company and Subsidiary (Unaudited)
	Condensed Consolidated Balance Sheets	910
	Condensed Consolidated Statements of Income	1011
	Condensed Consolidated Statements of Comprehensive Income	1011
	Condensed Consolidated Statements of Common Stockholder's Equity	1112
	Condensed Consolidated Statements of Cash Flows	1213

	Public Service Company of New Hampshire and Subsidiaries (Unaudited)
	Condensed Consolidated Balance Sheets	1314
	Condensed Consolidated Statements of Income	1415
	Condensed Consolidated Statements of Comprehensive Income	1415
	Condensed Consolidated Statements of Common Stockholder's Equity	1516
	Condensed Consolidated Statements of Cash Flows	1617

	Combined Notes to Condensed Financial Statements (Unaudited)	1718

ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations
	Eversource Energy and Subsidiaries	42
	The Connecticut Light and Power Company, NSTAR Electric Company and Subsidiary, and Public Service Company of New Hampshire and Subsidiaries	5862

ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	6669

ITEM 4.	Controls and Procedures	6669

PART II – OTHER INFORMATION

ITEM 1.	Legal Proceedings	6770

ITEM 1A.	Risk Factors	6770

ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6771

ITEM 6.	Exhibits	6872

SIGNATURES		7074

iii

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	As of September 30, 2019			As of December 31, 2018			As of September 30, 2020			As of December 31, 2019

ASSETS
Current Assets:
Cash	$	22,688		$	108,068
Receivables, Net	993,396			994,055
Cash and Cash Equivalents							$	729,993		$	15,432
Receivables, Net (net of allowance for uncollectible accounts of $294,972 and $224,821 as of September 30, 2020 and December 31, 2019, respectively)							1,113,495			989,383
Unbilled Revenues	150,394			176,285			155,961			181,006
Fuel, Materials, Supplies and REC Inventory	204,012			238,042			214,300			235,471
Regulatory Assets	538,162			514,779			762,883			651,112
Prepayments and Other Current Assets	312,253			260,995			243,781			342,135
Total Current Assets	2,220,905			2,292,224			3,220,413			2,414,539

Property, Plant and Equipment, Net	26,911,877			25,610,428			29,092,981			27,585,470

Deferred Debits and Other Assets:
Regulatory Assets	4,292,560			4,631,137			4,883,165			4,863,639
Goodwill	4,427,266			4,427,266			4,403,666			4,427,266
Investments in Unconsolidated Affiliates	861,687			464,286			903,177			871,633
Marketable Securities	404,804			417,508			438,839			449,130
Other Long-Term Assets	606,295			398,407			565,104			512,238
Total Deferred Debits and Other Assets	10,592,612			10,338,604			11,193,951			11,123,906

Total Assets	$	39,725,394		$	38,241,256		$	43,507,345		$	41,123,915

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	712,500		$	910,000		$	60,500		$	889,084
Long-Term Debt – Current Portion	853,066			837,319			1,078,186			327,411
Rate Reduction Bonds – Current Portion	43,210			52,332			43,210			43,210
Accounts Payable	892,106			1,119,995			1,222,058			1,147,872
Regulatory Liabilities	441,189			370,230			464,673			361,152
Other Current Liabilities	806,839			823,006			765,443			836,834
Total Current Liabilities	3,748,910			4,112,882			3,634,070			3,605,563

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	3,604,791			3,506,030			3,960,672			3,755,777
Regulatory Liabilities	3,644,477			3,609,475			3,711,488			3,658,042
Derivative Liabilities	357,869			379,562			312,933			338,710
Asset Retirement Obligations							499,859			488,511
Accrued Pension, SERP and PBOP	821,172			962,510			1,163,229			1,370,245
Other Long-Term Liabilities	1,290,704			1,196,336			856,285			810,553
Total Deferred Credits and Other Liabilities	9,719,013			9,653,913			10,504,466			10,421,838

Long-Term Debt	13,440,165			12,248,743			14,736,310			13,770,828

Rate Reduction Bonds	540,122			583,331			496,912			540,122

Noncontrolling Interest – Preferred Stock of Subsidiaries	155,570			155,570			155,570			155,570

Common Shareholders' Equity:
Common Shares	1,699,292			1,669,392			1,789,092			1,729,292
Capital Surplus, Paid In	6,675,889			6,241,222			7,996,976			7,087,768
Retained Earnings	4,100,220			3,953,974			4,535,860			4,177,048
Accumulated Other Comprehensive Loss	(52,017		)	(60,000		)	(60,397		)	(65,059		)
Treasury Stock	(301,770		)	(317,771		)	(281,514		)	(299,055		)
Common Shareholders' Equity	12,121,614			11,486,817			13,980,017			12,629,994

Commitments and Contingencies (Note 9)

Total Liabilities and Capitalization	$	39,725,394		$	38,241,256		$	43,507,345		$	41,123,915

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

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,				For the Nine Months Ended September 30,				For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars, Except Share Information)	2019		2018		2019		2018		2020		2019		2020		2019

Operating Revenues	$	2,175,797	$	2,271,425	$	6,476,084	$	6,413,243	$	2,343,642	$	2,175,797	$	6,670,497	$	6,476,084

Operating Expenses:
Purchased Power, Fuel and Transmission	730,255		842,291		2,326,041		2,442,953		806,254		730,255		2,312,957		2,326,041
Operations and Maintenance	331,054		344,475		994,660		970,881		332,031		331,054		1,006,148		994,660
Depreciation	222,599		208,671		656,632		612,077		244,453		222,599		721,179		656,632
Amortization	73,854		92,711		183,760		174,108		57,515		73,854		130,687		183,760
Energy Efficiency Programs	136,832		129,965		382,785		366,162		145,047		136,832		408,794		382,785
Taxes Other Than Income Taxes	171,965		187,291		537,636		547,155		197,112		171,965		556,726		537,636
Impairment of Northern Pass Transmission	—		—		239,644		—		0		0		0		239,644
Total Operating Expenses	1,666,559		1,805,404		5,321,158		5,113,336		1,782,412		1,666,559		5,136,491		5,321,158
Operating Income	509,238		466,021		1,154,926		1,299,907		561,230		509,238		1,534,006		1,154,926
Interest Expense	135,216		125,201		399,654		372,734		134,066		135,216		403,067		399,654
Other Income, Net	26,968		16,718		103,818		100,656		29,218		26,968		83,565		103,818
Income Before Income Tax Expense	400,990		357,538		859,090		1,027,829		456,382		400,990		1,214,504		859,090
Income Tax Expense	80,226		66,278		194,435		220,497		108,242		80,226		275,621		194,435
Net Income	320,764		291,260		664,655		807,332		348,140		320,764		938,883		664,655
Net Income Attributable to Noncontrolling Interests	1,880		1,880		5,639		5,639		1,880		1,880		5,639		5,639
Net Income Attributable to Common Shareholders	$	318,884	$	289,380	$	659,016	$	801,693	$	346,260	$	318,884	$	933,244	$	659,016

Basic Earnings Per Common Share	$	0.98	$	0.91	$	2.06	$	2.53	$	1.01	$	0.98	$	2.77	$	2.06

Diluted Earnings Per Common Share	$	0.98	$	0.91	$	2.05	$	2.52	$	1.01	$	0.98	$	2.76	$	2.05

Weighted Average Common Shares Outstanding:
Basic	324,037,169		317,360,110		320,442,253		317,367,252		343,076,614		324,037,169		337,375,172		320,442,253
Diluted	326,008,342		317,967,311		321,570,926		317,948,498		343,773,602		326,008,342		338,424,100		321,570,926

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

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended September 30,						For the Nine Months Ended September 30,						For the Three Months Ended September 30,						For the Nine Months Ended September 30,
(Thousands of Dollars)	2019			2018			2019			2018			2020			2019			2020			2019

Net Income	$	320,764		$	291,260		$	664,655		$	807,332		$	348,140		$	320,764		$	938,883		$	664,655
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	367			432			945			1,627			602			367			1,218			945
Changes in Unrealized Gains/(Losses) on Marketable Securities	169			(136		)	1,268			(724		)
Changes in Unrealized (Losses)/Gains on Marketable Securities													(134		)	169			295			1,268
Changes in Funded Status of Pension, SERP and PBOP Benefit Plans	1,088			1,110			5,770			5,918			1,693			1,088			3,149			5,770
Other Comprehensive Income, Net of Tax	1,624			1,406			7,983			6,821			2,161			1,624			4,662			7,983
Comprehensive Income Attributable to Noncontrolling Interests	(1,880		)	(1,880		)	(5,639		)	(5,639		)	(1,880		)	(1,880		)	(5,639		)	(5,639		)
Comprehensive Income Attributable to Common Shareholders	$	320,508		$	290,786		$	666,999		$	808,514		$	348,421		$	320,508		$	937,906		$	666,999

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

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

(Unaudited)


	For the Nine Months Ended September 30, 2019																		For the Nine Months Ended September 30, 2020
	Common Shares			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Common Shareholders' Equity			Common Shares			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information)	Shares	Amount																	Shares	Amount
Balance as of January 1, 2019	316,885,808	$	1,669,392	$	6,241,222		$	3,953,974		$	(60,000	)	$	(317,771	)	$	11,486,817
Balance as of January 1, 2020																			329,880,645	$	1,729,292	$	7,087,768		$	4,177,048		$	(65,059	)	$	(299,055	)	$	12,629,994
Net Income							310,558									310,558									336,633									336,633
Dividends on Common Shares - $0.535 Per Share							(169,757		)							(169,757		)
Dividends on Common Shares - $0.5675 Per Share																									(187,462		)							(187,462		)
Dividends on Preferred Stock							(1,880		)							(1,880		)							(1,880		)							(1,880		)
Issuance of Common Shares - $5 par value																			5,960,000	29,800		402,300												432,100
Long-Term Incentive Plan Activity				(16,609		)										(16,609		)				(15,295		)										(15,295		)
Issuance of Treasury Shares	461,662			17,476									8,633			26,109			570,542			17,230									10,516			27,746
Capital Stock Expense																						(12,314		)										(12,314		)
Adoption of New Accounting Standard (See Note 1B)																									(1,514		)							(1,514		)
Other Comprehensive Income										2,196						2,196												1,948						1,948
Balance as of March 31, 2019	317,347,470	1,669,392		6,242,089			4,092,895			(57,804		)	(309,138		)	11,637,434
Balance as of March 31, 2020																			336,411,187	1,759,092		7,479,689			4,322,825			(63,111		)	(288,539		)	13,209,956
Net Income							33,334									33,334									254,112									254,112
Dividends on Common Shares - $0.535 Per Share							(169,857		)							(169,857		)
Dividends on Common Shares - $0.5675 Per Share																									(190,964		)							(190,964		)
Dividends on Preferred Stock							(1,880		)							(1,880		)							(1,880		)							(1,880		)
Issuance of Common Shares - $5 par value	5,980,000	29,900		403,650												433,550			6,000,000	30,000		487,560												517,560
Long-Term Incentive Plan Activity				6,470												6,470						7,694												7,694
Issuance of Treasury Shares	246,969			13,448									4,579			18,027			216,675			12,524									4,024			16,548
Capital Stock Expense				(6,648		)										(6,648		)				(8,321		)										(8,321		)
Other Comprehensive Income										4,163						4,163												553						553
Balance as of June 30, 2019	323,574,439	1,699,292		6,659,009			3,954,492			(53,641		)	(304,559		)	11,954,593
Balance as of June 30, 2020																			342,627,862	1,789,092		7,979,146			4,384,093			(62,558		)	(284,515		)	13,805,258
Net Income							320,764									320,764									348,140									348,140
Dividends on Common Shares - $0.535 Per Share							(173,156		)							(173,156		)
Dividends on Common Shares - $0.5675 Per Share																									(194,493		)							(194,493		)
Dividends on Preferred Stock							(1,880		)							(1,880		)							(1,880		)							(1,880		)
Long-Term Incentive Plan Activity				6,697												6,697						6,921												6,921
Issuance of Treasury Shares	158,984			10,183									2,789			12,972			169,611			10,909									3,001			13,910
Other Comprehensive Income										1,624						1,624												2,161						2,161
Balance as of September 30, 2019	323,733,423	$	1,699,292	$	6,675,889		$	4,100,220		$	(52,017	)	$	(301,770	)	$	12,121,614
Balance as of September 30, 2020																			342,797,473	$	1,789,092	$	7,996,976		$	4,535,860		$	(60,397	)	$	(281,514	)	$	13,980,017

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

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

(Unaudited)


	For the Nine Months Ended September 30, 2018																		For the Nine Months Ended September 30, 2019
	Common Shares			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Common Shareholders' Equity			Common Shares			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss			Treasury Stock			Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information)	Shares	Amount																	Shares	Amount
Balance as of January 1, 2018	316,885,808	$	1,669,392	$	6,239,940		$	3,561,084		$	(66,403	)	$	(317,771	)	$	11,086,242
Balance as of January 1, 2019																			316,885,808	$	1,669,392	$	6,241,222		$	3,953,974		$	(60,000	)	$	(317,771	)	$	11,486,817
Net Income							271,426									271,426									310,558									310,558
Dividends on Common Shares - $0.505 Per Share							(160,027		)							(160,027		)
Dividends on Common Shares - $0.535 Per Share																									(169,757		)							(169,757		)
Dividends on Preferred Stock							(1,880		)							(1,880		)							(1,880		)							(1,880		)
Long-Term Incentive Plan Activity				(15,320		)										(15,320		)				(16,609		)										(16,609		)
Issuance of Treasury Shares																			461,662			17,476									8,633			26,109
Other Comprehensive Income										3,273						3,273												2,196						2,196
Balance as of March 31, 2018	316,885,808	1,669,392		6,224,620			3,670,603			(63,130		)	(317,771		)	11,183,714
Balance as of March 31, 2019																			317,347,470	1,669,392		6,242,089			4,092,895			(57,804		)	(309,138		)	11,637,434
Net Income							244,647									244,647									33,334									33,334
Dividends on Common Shares - $0.505 Per Share							(160,027		)							(160,027		)
Dividends on Common Shares - $0.535 Per Share																									(169,857		)							(169,857		)
Dividends on Preferred Stock																									(1,880		)							(1,880		)
Issuance of Common Shares - $5 par value																			5,980,000	29,900		403,650												433,550
Long-Term Incentive Plan Activity																						6,470												6,470
Issuance of Treasury Shares																			246,969			13,448									4,579			18,027
Capital Stock Expense																						(6,648		)										(6,648		)
Other Comprehensive Income																												4,163						4,163
Balance as of June 30, 2019																			323,574,439	1,699,292		6,659,009			3,954,492			(53,641		)	(304,559		)	11,954,593
Net Income																									320,764									320,764
Dividends on Common Shares - $0.535 Per Share																									(173,156		)							(173,156		)
Dividends on Preferred Stock							(1,880		)							(1,880		)							(1,880		)							(1,880		)
Long-Term Incentive Plan Activity				4,627												4,627						6,697												6,697
Issuance of Treasury Shares																			158,984			10,183									2,789			12,972
Other Comprehensive Income										2,142						2,142												1,624						1,624
Balance as of June 30, 2018	316,885,808	1,669,392		6,229,247			3,753,343			(60,988		)	(317,771		)	11,273,223
Net Income							291,260									291,260
Dividends on Common Shares - $0.505 Per Share							(160,028		)							(160,028		)
Dividends on Preferred Stock							(1,880		)							(1,880		)
Long-Term Incentive Plan Activity				4,797												4,797
Other Comprehensive Income										1,406						1,406
Balance as of September 30, 2018	316,885,808	$	1,669,392	$	6,234,044		$	3,882,695		$	(59,582	)	$	(317,771	)	$	11,408,778
Balance as of September 30, 2019																			323,733,423	$	1,699,292	$	6,675,889		$	4,100,220		$	(52,017	)	$	(301,770	)	$	12,121,614

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

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Nine Months Ended September 30,
(Thousands of Dollars)	2019			2018			2020			2019

Operating Activities:
Net Income	$	664,655		$	807,332		$	938,883		$	664,655
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	656,632			612,077			721,179			656,632
Deferred Income Taxes	73,487			70,402			156,795			73,487
Uncollectible Expense	46,417			50,720			31,101			46,417
Pension, SERP and PBOP Expense, Net	18,507			5,192			9,153			18,507
Pension and PBOP Contributions	(120,373		)	(188,874		)	(107,985		)	(120,373		)
Regulatory Overrecoveries, Net	80,688			189,932
Regulatory (Under)/Over Recoveries, Net							(29,287		)	80,688
Amortization	183,760			174,108			130,687			183,760
Proceeds from DOE Spent Nuclear Fuel Litigation	68,840			—			0			68,840
Impairment of Northern Pass Transmission	239,644			—			0			239,644
Other	(185,625		)	(129,039		)	(69,216		)	(185,625		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(57,011		)	(212,326		)	(193,895		)	(57,011		)
Fuel, Materials, Supplies and REC Inventory	34,030			44,702			21,102			34,030
Taxes Receivable/Accrued, Net	53,687			70,885			89,759			53,687
Accounts Payable	(157,355		)	(72,591		)	(121,034		)	(157,355		)
Other Current Assets and Liabilities, Net	(105,133		)	(14,858		)	(81,033		)	(105,133		)
Net Cash Flows Provided by Operating Activities	1,494,850			1,407,662			1,496,209			1,494,850

Investing Activities:
Investments in Property, Plant and Equipment	(2,129,037		)	(1,885,081		)	(2,101,564		)	(2,129,037		)
Proceeds from Sales of Marketable Securities	458,322			405,276			386,712			458,322
Purchases of Marketable Securities	(405,095		)	(396,277		)	(391,368		)	(405,095		)
Proceeds from the Sale of PSNH Generation Assets	—			193,924
Proceeds from the Sale of Hingham Water System							110,536			0
Investments in Unconsolidated Affiliates, Net	(374,913		)	(27,342		)	(31,677		)	(374,913		)
Other Investing Activities	(1,126		)	3,937			17,647			(1,126		)
Net Cash Flows Used in Investing Activities	(2,451,849		)	(1,705,563		)	(2,009,714		)	(2,451,849		)

Financing Activities:
Issuance of Common Shares, Net of Issuance Costs	426,902			—			929,025			426,902
Cash Dividends on Common Shares	(495,571		)	(480,082		)	(555,655		)	(495,571		)
Cash Dividends on Preferred Stock	(5,639		)	(5,639		)	(5,639		)	(5,639		)
Decrease in Notes Payable	(197,500		)	(222,110		)	(1,174,870		)	(197,500		)
Issuance of Rate Reduction Bonds	—			635,663
Repayment of Rate Reduction Bonds	(52,332		)	—			(43,210		)	(52,332		)
Issuance of Long-Term Debt	1,475,000			1,300,000			2,360,000			1,475,000
Retirement of Long-Term Debt	(250,855		)	(860,855		)	(302,236		)	(250,855		)
Other Financing Activities	(450		)	(20,361		)	18,030			(450		)
Net Cash Flows Provided by Financing Activities	899,555			346,616			1,225,445			899,555
Net (Decrease)/Increase in Cash and Restricted Cash	(57,444		)	48,715
Cash and Restricted Cash - Beginning of Period	209,324			85,890
Cash and Restricted Cash - End of Period	$	151,880		$	134,605
Net Increase/(Decrease) in Cash and Restricted Cash							711,940			(57,444		)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period							117,063			209,324
Cash, Cash Equivalents and Restricted Cash - End of Period							$	829,003		$	151,880

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	As of September 30, 2019		As of December 31, 2018		As of September 30, 2020		As of December 31, 2019

ASSETS
Current Assets:
Cash	$	9,286	$	87,721	$	8,173	$	0
Receivables, Net	428,050		397,026
Receivables, Net (net of allowance for uncollectible accounts of $150,758 and $97,348 as of September 30, 2020 and December 31, 2019, respectively)					473,830		400,927
Accounts Receivable from Affiliated Companies	34,702		23,082		43,950		24,577
Unbilled Revenues	48,211		56,971		50,111		56,465
Materials and Supplies	52,209		44,529		57,744		50,700
Regulatory Assets	173,339		125,155		273,792		178,607
Prepaid Property Taxes	66,510		19,555		73,511		22,799
Prepayments and Other Current Assets	24,236		40,724		63,097		50,385
Total Current Assets	836,543		794,763		1,044,208		784,460

Property, Plant and Equipment, Net	9,456,562		8,909,701		10,065,346		9,625,765

Deferred Debits and Other Assets:
Regulatory Assets	1,404,502		1,505,488		1,732,739		1,557,261
Other Long-Term Assets	229,092		199,767		241,663		217,705
Total Deferred Debits and Other Assets	1,633,594		1,705,255		1,974,402		1,774,966

Total Assets	$	11,926,699	$	11,409,719	$	13,083,956	$	12,185,191

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	173,100	$	—	$	235,900	$	63,800
Long-Term Debt – Current Portion	—		250,000
Accounts Payable	280,463		324,983		554,489		374,698
Accounts Payable to Affiliated Companies	76,916		26,452		107,212		97,793
Obligations to Third Party Suppliers	57,823		56,248		52,883		56,952
Regulatory Liabilities	168,053		109,614		164,946		82,763
Derivative Liabilities	64,572		55,058		69,218		67,804
Other Current Liabilities	169,600		161,088		131,939		132,339
Total Current Liabilities	990,527		983,443		1,316,587		876,149

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,205,687		1,166,784		1,350,403		1,244,551
Regulatory Liabilities	1,159,909		1,122,157		1,196,255		1,164,991
Derivative Liabilities	357,728		379,536		312,933		338,594
Accrued Pension, SERP and PBOP	248,557		282,771		325,173		391,159
Other Long-Term Liabilities	149,293		155,495		153,938		147,586
Total Deferred Credits and Other Liabilities	3,121,174		3,106,743		3,338,702		3,286,881

Long-Term Debt	3,518,464		3,004,016		3,518,115		3,518,136

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

Common Stockholder's Equity:
Common Stock	60,352		60,352		60,352		60,352
Capital Surplus, Paid In	2,410,765		2,410,765		2,660,765		2,535,765
Retained Earnings	1,708,892		1,727,899		2,072,928		1,791,392
Accumulated Other Comprehensive Income	325		301		307		316
Common Stockholder's Equity	4,180,334		4,199,317		4,794,352		4,387,825

Commitments and Contingencies (Note 9)

Total Liabilities and Capitalization	$	11,926,699	$	11,409,719	$	13,083,956	$	12,185,191

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,				For the Nine Months Ended September 30,				For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars)	2019		2018		2019		2018		2020		2019		2020		2019

Operating Revenues	$	853,943	$	865,028	$	2,444,034	$	2,344,903	$	994,270	$	853,943	$	2,711,394	$	2,444,034

Operating Expenses:
Purchased Power and Transmission	299,017		314,571		865,389		850,794		399,117		299,017		1,089,232		865,389
Operations and Maintenance	135,077		128,523		399,065		355,500		147,487		135,077		417,717		399,065
Depreciation	76,250		72,017		224,095		208,899		80,583		76,250		238,735		224,095
Amortization of Regulatory Assets, Net	30,406		54,031		78,453		97,437		36,365		30,406		37,215		78,453
Energy Efficiency Programs	40,129		30,240		86,897		71,606		41,829		40,129		109,655		86,897
Taxes Other Than Income Taxes	82,781		92,987		261,244		267,662		97,715		82,781		260,571		261,244
Total Operating Expenses	663,660		692,369		1,915,143		1,851,898		803,096		663,660		2,153,125		1,915,143
Operating Income	190,283		172,659		528,891		493,005		191,174		190,283		558,269		528,891
Interest Expense	39,520		37,609		112,274		113,107		38,369		39,520		114,972		112,274
Other Income, Net	4,831		7,098		11,564		20,722		5,917		4,831		16,273		11,564
Income Before Income Tax Expense	155,594		142,148		428,181		400,620		158,722		155,594		459,570		428,181
Income Tax Expense	43,907		41,818		101,219		102,010		38,625		43,907		103,464		101,219
Net Income	$	111,687	$	100,330	$	326,962	$	298,610	$	120,097	$	111,687	$	356,106	$	326,962

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

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended September 30,						For the Nine Months Ended September 30,						For the Three Months Ended September 30,						For the Nine Months Ended September 30,
(Thousands of Dollars)	2019			2018			2019			2018			2020			2019			2020			2019

Net Income	$	111,687		$	100,330		$	326,962		$	298,610		$	120,097		$	111,687		$	356,106		$	326,962
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	(7		)	(7		)	(20		)	58			(7		)	(7		)	(20		)	(20		)
Changes in Unrealized Gains/(Losses) on Marketable Securities	6			(5		)	44			(21		)
Changes in Unrealized (Losses)/Gains on Marketable Securities													(4		)	6			11			44
Other Comprehensive (Loss)/Income, Net of Tax	(1		)	(12		)	24			37			(11		)	(1		)	(9		)	24
Comprehensive Income	$	111,686		$	100,318		$	326,986		$	298,647		$	120,086		$	111,686		$	356,097		$	326,986

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)


	For the Nine Months Ended September 30, 2019																For the Nine Months Ended September 30, 2020
	Common Stock			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Income				Total Common Stockholder's Equity			Common Stock			Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Income			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount				Stock							Amount
Balance as of January 1, 2019	6,035,205	$	60,352			$		2,410,765		$	1,727,899					$	301	$	4,199,317
Balance as of January 1, 2020																	6,035,205	$	60,352	$	2,535,765	$	1,791,392		$	316		$	4,387,825
Net Income							110,471							110,471								118,738						118,738
Dividends on Preferred Stock							(1,390		)					(1,390		)						(1,390		)				(1,390		)
Dividends on Common Stock							(99,000		)					(99,000		)						(69,500		)				(69,500		)
Other Comprehensive Income										17				17
Balance as of March 31, 2019	6,035,205	60,352		2,410,765			1,737,980			318				4,209,415
Adoption of New Accounting Standard (See Note 1B)																						(900		)				(900		)
Other Comprehensive Loss																									(1		)	(1		)
Balance as of March 31, 2020																	6,035,205	60,352		2,535,765		1,838,340			315			4,434,772
Net Income							104,804							104,804								117,271						117,271
Dividends on Preferred Stock							(1,390		)					(1,390		)						(1,390		)				(1,390		)
Dividends on Common Stock							(176,400		)					(176,400		)
Other							1							1
Other Comprehensive Income										8				8											3			3
Balance as of June 30, 2019	6,035,205	60,352		2,410,765			1,664,995			326				4,136,438
Balance as of June 30, 2020																	6,035,205	60,352		2,535,765		1,954,221			318			4,550,656
Net Income							111,687							111,687								120,097						120,097
Dividends on Preferred Stock							(1,390		)					(1,390		)						(1,390		)				(1,390		)
Dividends on Common Stock							(66,400		)					(66,400		)
Capital Contributions from Eversource Parent																				125,000								125,000
Other Comprehensive Loss										(1		)		(1		)									(11		)	(11		)
Balance as of September 30, 2019	6,035,205	$	60,352	$	2,410,765		$	1,708,892		$	325			$	4,180,334
Balance as of September 30, 2020																	6,035,205	$	60,352	$	2,660,765	$	2,072,928		$	307		$	4,794,352


	For the Nine Months Ended September 30, 2018																For the Nine Months Ended September 30, 2019
	Common Stock			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Income				Total Common Stockholder's Equity			Common Stock			Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Income			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount				Stock							Amount
Balance as of January 1, 2018	6,035,205	$	60,352			$		2,110,765		$	1,415,741					$	269	$	3,587,127
Balance as of January 1, 2019																	6,035,205	$	60,352	$	2,410,765	$	1,727,899		$	301		$	4,199,317
Net Income							98,568							98,568								110,471						110,471
Dividends on Preferred Stock							(1,390		)					(1,390		)						(1,390		)				(1,390		)
Dividends on Common Stock							(60,000		)					(60,000		)						(99,000		)				(99,000		)
Capital Contributions from Eversource Parent				9,000										9,000
Other Comprehensive Income										40				40											17			17
Balance as of March 31, 2018	6,035,205	60,352		2,119,765			1,452,919			309				3,633,345
Balance as of March 31, 2019																	6,035,205	60,352		2,410,765		1,737,980			318			4,209,415
Net Income							99,712							99,712								104,804						104,804
Dividends on Preferred Stock							(1,390		)					(1,390		)						(1,390		)				(1,390		)
Capital Contributions from Eversource Parent				91,000										91,000
Dividends on Common Stock																						(176,400		)				(176,400		)
Other																						1						1
Other Comprehensive Income										9				9											8			8
Balance as of June 30, 2018	6,035,205	60,352		2,210,765			1,551,241			318				3,822,676
Balance as of June 30, 2019																	6,035,205	60,352		2,410,765		1,664,995			326			4,136,438
Net Income							100,330							100,330								111,687						111,687
Dividends on Preferred Stock							(1,389		)					(1,389		)						(1,390		)				(1,390		)
Dividends on Common Stock																						(66,400		)				(66,400		)
Other Comprehensive Loss										(12		)		(12		)									(1		)	(1		)
Balance as of September 30, 2018	6,035,205	$	60,352	$	2,210,765		$	1,650,182		$	306			$	3,921,605
Balance as of September 30, 2019																	6,035,205	$	60,352	$	2,410,765	$	1,708,892		$	325		$	4,180,334

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Nine Months Ended September 30,
(Thousands of Dollars)	2019			2018			2020			2019

Operating Activities:
Net Income	$	326,962		$	298,610		$	356,106		$	326,962
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	224,095			208,899			238,735			224,095
Deferred Income Taxes	19,999			28,637			92,590			19,999
Uncollectible Expense	12,084			12,135			10,013			12,084
Pension, SERP, and PBOP Expense, Net	9,843			6,594			8,629			9,843
Pension Contributions	(24,000		)	(41,150		)	(23,200		)	(24,000		)
Regulatory Over/(Under) Recoveries, Net	32,435			(1,136		)
Regulatory (Under)/Over Recoveries, Net							(32,051		)	32,435
Amortization of Regulatory Assets, Net	78,453			97,437			37,215			78,453
Other	(66,737		)	(55,827		)	(63,525		)	(66,737		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(70,996		)	(126,513		)	(153,464		)	(70,996		)
Taxes Receivable/Accrued, Net	32,708			72,702			(1,515		)	32,708
Accounts Payable	8,604			(15,303		)	(1,976		)	8,604
Other Current Assets and Liabilities, Net	(51,937		)	(33,965		)	(68,316		)	(51,937		)
Net Cash Flows Provided by Operating Activities	531,513			451,120			399,241			531,513

Investing Activities:
Investments in Property, Plant and Equipment	(699,288		)	(660,673		)	(609,690		)	(699,288		)
Other Investing Activities	645			167			496			645
Net Cash Flows Used in Investing Activities	(698,643		)	(660,506		)	(609,194		)	(698,643		)

Financing Activities:
Cash Dividends on Common Stock	(341,800		)	(60,000		)	(69,500		)	(341,800		)
Cash Dividends on Preferred Stock	(4,169		)	(4,169		)	(4,169		)	(4,169		)
Capital Contributions from Eversource Parent	—			100,000			125,000			0
Issuance of Long-Term Debt	500,000			500,000			0			500,000
Retirement of Long-Term Debt	(250,000		)	(300,000		)	0			(250,000		)
Increase/(Decrease) in Notes Payable to Eversource Parent	173,100			(23,600		)
Increase in Notes Payable to Eversource Parent							172,100			173,100
Other Financing Activities	12,667			(7,584		)	(1,214		)	12,667
Net Cash Flows Provided by Financing Activities	89,798			204,647			222,217			89,798
Net Decrease in Cash and Restricted Cash	(77,332		)	(4,739		)
Net Increase/(Decrease) in Cash and Restricted Cash							12,264			(77,332		)
Cash and Restricted Cash - Beginning of Period	91,613			9,619			4,971			91,613
Cash and Restricted Cash - End of Period	$	14,281		$	4,880		$	17,235		$	14,281

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	As of September 30, 2019			As of December 31, 2018			As of September 30, 2020		As of December 31, 2019

ASSETS
Current Assets:
Cash	$	264		$	1,606		$	87	$	52
Receivables, Net	385,689			361,296
Receivables, Net (net of allowance for uncollectible accounts of $76,760 and $75,406 as of September 30, 2020 and December 31, 2019, respectively)							439,504		346,785
Accounts Receivable from Affiliated Companies	39,386			31,344			30,599		29,914
Unbilled Revenues	42,794			34,518			44,936		37,482
Materials, Supplies and REC Inventory	90,169			114,202			96,351		124,060
Regulatory Assets	201,215			241,747			278,604		285,591
Prepayments and Other Current Assets	11,564			51,960			17,613		31,150
Total Current Assets	771,081			836,673			907,694		855,034

Property, Plant and Equipment, Net	9,264,180			8,794,700			9,943,408		9,472,770

Deferred Debits and Other Assets:
Regulatory Assets	1,159,056			1,196,512			1,194,092		1,250,029
Prepaid PBOP	152,978			132,810			192,579		166,058
Other Long-Term Assets	149,785			109,764			148,282		144,368
Total Deferred Debits and Other Assets	1,461,819			1,439,086			1,534,953		1,560,455

Total Assets	$	11,497,080		$	11,070,459		$	12,386,055	$	11,888,259

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	28,000		$	278,500		$	60,500	$	10,500
Notes Payable to Eversource Parent	48,700			—			36,600		30,300
Long-Term Debt – Current Portion	95,000			—			250,000		95,000
Accounts Payable	304,346			384,398			304,025		363,691
Accounts Payable to Affiliated Companies	84,898			89,636			84,942		96,307
Obligations to Third Party Suppliers	110,243			109,547			115,194		108,827
Renewable Portfolio Standards Compliance Obligations	113,330			139,898			92,000		150,429
Regulatory Liabilities	199,381			190,620			210,744		209,180
Other Current Liabilities	112,577			74,872			104,725		71,333
Total Current Liabilities	1,096,475			1,267,471			1,258,730		1,135,567

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,329,266			1,294,467			1,394,072		1,357,265
Regulatory Liabilities	1,519,631			1,513,279			1,534,760		1,516,585
Accrued Pension and SERP	20,544			14,145			84,088		108,243
Other Long-Term Liabilities	325,617			263,096			353,030		320,629
Total Deferred Credits and Other Liabilities	3,195,058			3,084,987			3,365,950		3,302,722

Long-Term Debt	3,246,631			2,944,846			3,392,836		3,247,086

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

Common Stockholder's Equity:
Common Stock	—			—			0		0
Capital Surplus, Paid In	1,663,442			1,633,442			1,813,442		1,813,442
Retained Earnings	2,253,509			2,098,091			2,511,742		2,346,287
Accumulated Other Comprehensive Loss	(1,035		)	(1,378		)
Accumulated Other Comprehensive Income							355		155
Common Stockholder's Equity	3,915,916			3,730,155			4,325,539		4,159,884

Commitments and Contingencies (Note 9)

Total Liabilities and Capitalization	$	11,497,080		$	11,070,459		$	12,386,055	$	11,888,259

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,				For the Nine Months Ended September 30,				For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars)	2019		2018		2019		2018		2020		2019		2020		2019

Operating Revenues	$	878,669	$	939,460	$	2,358,174	$	2,400,324	$	875,371	$	878,669	$	2,270,174	$	2,358,174

Operating Expenses:
Purchased Power and Transmission	300,726		383,208		859,227		981,895		267,375		300,726		702,117		859,227
Operations and Maintenance	120,917		123,634		342,804		344,478		131,143		120,917		369,293		342,804
Depreciation	74,664		70,616		220,303		205,210		80,366		74,664		238,232		220,303
Amortization of Regulatory Assets, Net	27,296		17,149		73,064		35,467		22,527		27,296		69,139		73,064
Energy Efficiency Programs	84,409		89,430		227,042		229,408		85,244		84,409		210,666		227,042
Taxes Other Than Income Taxes	51,266		49,927		144,314		145,740		54,680		51,266		153,985		144,314
Total Operating Expenses	659,278		733,964		1,866,754		1,942,198		641,335		659,278		1,743,432		1,866,754
Operating Income	219,391		205,496		491,420		458,126		234,036		219,391		526,742		491,420
Interest Expense	29,322		26,958		85,442		80,780		31,029		29,322		95,000		85,442
Other Income, Net	10,735		13,697		32,479		40,567		12,802		10,735		38,152		32,479
Income Before Income Tax Expense	200,804		192,235		438,457		417,913		215,809		200,804		469,894		438,457
Income Tax Expense	45,864		51,640		99,769		112,247		50,081		45,864		106,309		99,769
Net Income	$	154,940	$	140,595	$	338,688	$	305,666	$	165,728	$	154,940	$	363,585	$	338,688

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

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended September 30,					For the Nine Months Ended September 30,					For the Three Months Ended September 30,					For the Nine Months Ended September 30,
(Thousands of Dollars)	2019		2018			2019		2018			2020			2019		2020			2019

Net Income	$	154,940	$	140,595		$	338,688	$	305,666		$	165,728		$	154,940	$	363,585		$	338,688
Other Comprehensive Income, Net of Tax:
Changes in Funded Status of SERP Benefit Plan	1		1			3		3			(43		)	1		(129		)	3
Qualified Cash Flow Hedging Instruments	109		110			328		328			109			109		327			328
Changes in Unrealized Gains/(Losses) on Marketable Securities	2		(1		)	12		(6		)
Changes in Unrealized (Losses)/Gains on Marketable Securities											(1		)	2		2			12
Other Comprehensive Income, Net of Tax	112		110			343		325			65			112		200			343
Comprehensive Income	$	155,052	$	140,705		$	339,031	$	305,991		$	165,793		$	155,052	$	363,785		$	339,031

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)


	For the Nine Months Ended September 30, 2019																For the Nine Months Ended September 30, 2020
	Common Stock			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss				Total Common Stockholder's Equity			Common Stock				Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Income		Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount				Stock				Accumulated Other Comprehensive Loss			Amount								Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Income		Total Common Stockholder's Equity
Balance as of January 1, 2019	200	$	—	Capital Surplus, Paid In		$	Retained Earnings	1,633,442		$	2,098,091			Total Common Stockholder's Equity		$	(1,378	)	$	3,730,155
Balance as of January 1, 2020																	200		$	0	$	1,813,442	$	2,346,287		$	155	$	4,159,884
Net Income							94,014							94,014									100,390					100,390
Dividends on Preferred Stock							(490		)					(490		)							(490		)			(490		)
Dividends on Common Stock							(60,600		)					(60,600		)							(196,500		)			(196,500		)
Capital Contributions from Eversource Parent				20,000										20,000
Adoption of New Accounting Standard (See Note 1B)																							(161		)			(161		)
Other Comprehensive Income										117				117												67		67
Balance as of March 31, 2019	200	—		1,653,442			2,131,015			(1,261		)		3,783,196
Balance as of March 31, 2020																	200		0		1,813,442		2,249,526			222		4,063,190
Net Income							89,734							89,734									97,468					97,468
Dividends on Preferred Stock							(490		)					(490		)							(490		)			(490		)
Dividends on Common Stock							(121,200		)					(121,200		)
Other Comprehensive Income										114				114												68		68
Balance as of June 30, 2019	200	—		1,653,442			2,099,059			(1,147		)		3,751,354
Balance as of June 30, 2020																	200		0		1,813,442		2,346,504			290		4,160,236
Net Income							154,940							154,940									165,728					165,728
Dividends on Preferred Stock							(490		)					(490		)							(490		)			(490		)
Capital Contributions from Eversource Parent				10,000										10,000
Other Comprehensive Income										112				112												65		65
Balance as of September 30, 2019	200	$	—	$	1,663,442		$	2,253,509		$	(1,035	)		$	3,915,916
Balance as of September 30, 2020																	200		$	0	$	1,813,442	$	2,511,742		$	355	$	4,325,539


	For the Nine Months Ended September 30, 2018																For the Nine Months Ended September 30, 2019
	Common Stock			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss				Total Common Stockholder's Equity			Common Stock				Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Loss			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount				Stock				Accumulated Other Comprehensive Loss			Amount								Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Loss			Total Common Stockholder's Equity
Balance as of January 1, 2018	200	$	—	Capital Surplus, Paid In		$	Retained Earnings	1,502,942		$	1,944,961			Total Common Stockholder's Equity		$	(1,823	)	$	3,446,080
Balance as of January 1, 2019																	200		$	0	$	1,633,442	$	2,098,091		$	(1,378	)	$	3,730,155
Net Income							77,149							77,149									94,014						94,014
Dividends on Preferred Stock							(490		)					(490		)							(490		)				(490		)
Dividends on Common Stock							(161,000		)					(161,000		)							(60,600		)				(60,600		)
Capital Contributions from Eversource Parent				92,500										92,500							20,000								20,000
Other							1							1
Other Comprehensive Income										106				106												117			117
Balance as of March 31, 2018	200	—		1,595,442			1,860,621			(1,717		)		3,454,346
Balance as of March 31, 2019																	200		0		1,653,442		2,131,015			(1,261		)	3,783,196
Net Income																							89,734						89,734
Dividends on Preferred Stock																							(490		)				(490		)
Dividends on Common Stock																							(121,200		)				(121,200		)
Other Comprehensive Income																										114			114
Balance as of June 30, 2019																	200		0		1,653,442		2,099,059			(1,147		)	3,751,354
Net Income							87,921							87,921									154,940						154,940
Dividends on Preferred Stock							(490		)					(490		)							(490		)				(490		)
Capital Contributions from Eversource Parent				8,000										8,000							10,000								10,000
Other Comprehensive Income										109				109												112			112
Balance as of June 30, 2018	200	—		1,603,442			1,948,052			(1,608		)		3,549,886
Net Income							140,595							140,595
Dividends on Preferred Stock							(490		)					(490		)
Capital Contributions from Eversource Parent				5,000										5,000
Other Comprehensive Income										110				110
Balance as of September 30, 2018	200	$	—	$	1,608,442		$	2,088,157		$	(1,498	)		$	3,695,101
Balance as of September 30, 2019																	200		$	0	$	1,663,442	$	2,253,509		$	(1,035	)	$	3,915,916

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Nine Months Ended September 30,
(Thousands of Dollars)	2019			2018			2020			2019

Operating Activities:
Net Income	$	338,688		$	305,666		$	363,585		$	338,688
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	220,303			205,210			238,232			220,303
Deferred Income Taxes	11,080			16,203			13,436			11,080
Uncollectible Expense	18,598			20,433			11,321			18,598
Pension, SERP and PBOP Income, Net	(9,779		)	(15,855		)	(13,714		)	(9,779		)
Pension and PBOP Contributions	(4,910		)	(60,454		)	(650		)	(4,910		)
Regulatory Overrecoveries, Net	46,543			180,797
Regulatory (Under)/Over Recoveries, Net							(20,047		)	46,543
Amortization of Regulatory Assets, Net	73,064			35,467			69,139			73,064
Other	(50,685		)	(49,178		)	(25,508		)	(50,685		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(68,167		)	(155,669		)	(104,528		)	(68,167		)
Materials, Supplies and REC Inventory	24,033			29,156			27,709			24,033
Taxes Receivable/Accrued, Net	66,917			42,148			55,405			66,917
Accounts Payable	(47,256		)	(13,178		)	(57,300		)	(47,256		)
Other Current Assets and Liabilities, Net	(31,495		)	33,543			(54,481		)	(31,495		)
Net Cash Flows Provided by Operating Activities	586,934			574,289			502,599			586,934

Investing Activities:
Investments in Property, Plant and Equipment	(636,214		)	(538,973		)	(655,039		)	(636,214		)
Other Investing Activities	67			46			138			67
Net Cash Flows Used in Investing Activities	(636,147		)	(538,927		)	(654,901		)	(636,147		)

Financing Activities:
Cash Dividends on Common Stock	(181,800		)	(161,000		)	(196,500		)	(181,800		)
Cash Dividends on Preferred Stock	(1,470		)	(1,470		)	(1,470		)	(1,470		)
Issuance of Long-Term Debt	400,000			—			400,000			400,000
Retirement of Long-Term Debt							(95,000		)	0
Capital Contributions from Eversource Parent	30,000			105,500			0			30,000
Increase in Notes Payable to Eversource Parent	48,700			16,000			6,300			48,700
(Decrease)/Increase in Notes Payable	(250,500		)	6,500
Increase/(Decrease) in Notes Payable							50,000			(250,500		)
Other Financing Activities	(3,868		)	(239		)	(4,931		)	(3,868		)
Net Cash Flows Provided by/(Used in) Financing Activities	41,062			(34,709		)
Net (Decrease)/Increase in Cash and Restricted Cash	(8,151		)	653
Net Cash Flows Provided by Financing Activities							158,399			41,062
Net Increase/(Decrease) in Cash and Restricted Cash							6,097			(8,151		)
Cash and Restricted Cash - Beginning of Period	14,659			14,708			6,312			14,659
Cash and Restricted Cash - End of Period	$	6,508		$	15,361		$	12,409		$	6,508

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

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	As of September 30, 2019			As of December 31, 2018			As of September 30, 2020			As of December 31, 2019

ASSETS
Current Assets:
Cash	$	1,647		$	1,439		$	767		$	413
Receivables, Net	107,096			104,854
Receivables, Net (net of allowance for uncollectible accounts of $13,972 and $10,497 as of September 30, 2020 and December 31, 2019, respectively)							121,125			99,934
Accounts Receivable from Affiliated Companies	23,882			8,444			11,280			6,763
Unbilled Revenues	38,901			47,145			40,003			48,146
Taxes Receivable	1,111			25,913
Materials, Supplies and REC Inventory	23,960			37,504			25,258			24,957
Regulatory Assets	78,097			67,228			103,570			84,053
Special Deposits	18,526			47,498			19,088			32,513
Prepayments and Other Current Assets	2,726			17,564			12,819			19,431
Total Current Assets	295,946			357,589			333,910			316,210

Property, Plant and Equipment, Net	3,031,985			2,880,073			3,319,483			3,129,506

Deferred Debits and Other Assets:
Regulatory Assets	792,332			862,288			808,784			861,672
Other Long-Term Assets	40,890			27,406			37,128			43,270
Total Deferred Debits and Other Assets	833,222			889,694			845,912			904,942

Total Assets	$	4,161,153		$	4,127,356		$	4,499,305		$	4,350,658

LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	42,100		$	57,000		$	29,100		$	27,000
Long-Term Debt – Current Portion	150,000			150,000			282,000			0
Rate Reduction Bonds – Current Portion	43,210			52,332			43,210			43,210
Accounts Payable	89,992			111,292			110,150			127,081
Accounts Payable to Affiliated Companies	35,940			26,029			25,728			37,946
Regulatory Liabilities	54,681			55,526			61,457			65,766
Accrued Interest							14,690			19,138
Other Current Liabilities	61,260			64,046			36,182			32,736
Total Current Liabilities	477,183			516,225			602,517			352,877

Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	500,391			481,221			525,422			506,212
Regulatory Liabilities	418,106			428,069			406,211			413,381
Accrued Pension, SERP and PBOP	88,492			124,457			123,609			157,638
Other Long-Term Liabilities	33,454			36,339			39,320			37,075
Total Deferred Credits and Other Liabilities	1,040,443			1,070,086			1,094,562			1,114,306

Long-Term Debt	951,471			655,173			816,974			951,620

Rate Reduction Bonds	540,122			583,331			496,912			540,122

Common Stockholder's Equity:
Common Stock	—			—			0			0
Capital Surplus, Paid In	678,134			678,134			903,134			903,134
Retained Earnings	475,770			627,258			586,090			490,306
Accumulated Other Comprehensive Loss	(1,970		)	(2,851		)	(884		)	(1,707		)
Common Stockholder's Equity	1,151,934			1,302,541			1,488,340			1,391,733

Commitments and Contingencies (Note 9)

Total Liabilities and Capitalization	$	4,161,153		$	4,127,356		$	4,499,305		$	4,350,658

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

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


	For the Three Months Ended September 30,				For the Nine Months Ended September 30,				For the Three Months Ended September 30,				For the Nine Months Ended September 30,
(Thousands of Dollars)	2019		2018		2019		2018		2020		2019		2020		2019

Operating Revenues	$	280,431	$	290,203	$	797,766	$	792,700	$	283,669	$	280,431	$	815,261	$	797,766

Operating Expenses:
Purchased Power, Fuel and Transmission	101,381		100,763		300,680		293,975
Purchased Power and Transmission									96,612		101,381		273,311		300,680
Operations and Maintenance	50,838		55,429		156,197		153,296		50,657		50,838		151,802		156,197
Depreciation	23,539		23,223		69,720		69,524		25,410		23,539		74,494		69,720
Amortization of Regulatory Assets, Net	20,421		27,357		39,944		41,318		7,360		20,421		39,034		39,944
Energy Efficiency Programs	7,300		5,863		20,229		15,694		11,081		7,300		29,231		20,229
Taxes Other Than Income Taxes	12,487		21,095		50,523		59,775		18,174		12,487		58,331		50,523
Total Operating Expenses	215,966		233,730		637,293		633,582		209,294		215,966		626,203		637,293
Operating Income	64,465		56,473		160,473		159,118		74,375		64,465		189,058		160,473
Interest Expense	16,378		16,593		44,654		43,977		14,942		16,378		44,029		44,654
Other Income, Net	4,634		16,095		14,640		24,253		4,065		4,634		10,882		14,640
Income Before Income Tax Expense	52,721		55,975		130,459		139,394		63,498		52,721		155,911		130,459
Income Tax Expense	11,842		15,309		29,947		37,857		16,347		11,842		37,527		29,947
Net Income	$	40,879	$	40,666	$	100,512	$	101,537	$	47,151	$	40,879	$	118,384	$	100,512

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

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)


	For the Three Months Ended September 30,					For the Nine Months Ended September 30,					For the Three Months Ended September 30,					For the Nine Months Ended September 30,
(Thousands of Dollars)	2019		2018			2019		2018			2020			2019		2020		2019

Net Income	$	40,879	$	40,666		$	100,512	$	101,537		$	47,151		$	40,879	$	118,384	$	100,512
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	268		268			806		835			268			268		806		806
Changes in Unrealized Gains/(Losses) on Marketable Securities	10		(7		)	75		(36		)
Changes in Unrealized (Losses)/Gains on Marketable Securities											(8		)	10		17		75
Other Comprehensive Income, Net of Tax	278		261			881		799			260			278		823		881
Comprehensive Income	$	41,157	$	40,927		$	101,393	$	102,336		$	47,411		$	41,157	$	119,207	$	101,393

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

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)


	For the Nine Months Ended September 30, 2019																For the Nine Months Ended September 30, 2020
	Common Stock			Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Loss				Total Common Stockholder's Equity			Common Stock				Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Loss			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount				Stock				Accumulated Other Comprehensive Loss			Amount								Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Loss			Total Common Stockholder's Equity
Balance as of January 1, 2019	301	$	—	Capital Surplus, Paid In		$	Retained Earnings	678,134		$	627,258			Total Common Stockholder's Equity		$	(2,851	)	$	1,302,541
Balance as of January 1, 2020																	301		$	0	$	903,134	$	490,306		$	(1,707	)	$	1,391,733
Net Income							32,781							32,781									39,601						39,601
Dividends on Common Stock							(19,000		)					(19,000		)							(22,300		)				(22,300		)
Adoption of New Accounting Standard (See Note 1B)																							(300		)				(300		)
Other Comprehensive Income										307				307												278			278
Balance as of March 31, 2019	301	—		678,134			641,039			(2,544		)		1,316,629
Balance as of March 31, 2020																	301		0		903,134		507,307			(1,429		)	1,409,012
Net Income							26,852							26,852									31,632						31,632
Dividends on Common Stock							(214,000		)					(214,000		)
Other Comprehensive Income										296				296												285			285
Balance as of June 30, 2019	301	—		678,134			453,891			(2,248		)		1,129,777
Balance as of June 30, 2020																	301		0		903,134		538,939			(1,144		)	1,440,929
Net Income							40,879							40,879									47,151						47,151
Dividends on Common Stock							(19,000		)					(19,000		)
Other Comprehensive Income										278				278												260			260
Balance as of September 30, 2019	301	$	—	$	678,134		$	475,770		$	(1,970	)		$	1,151,934
Balance as of September 30, 2020																	301		$	0	$	903,134	$	586,090		$	(884	)	$	1,488,340


	For the Nine Months Ended September 30, 2018																	For the Nine Months Ended September 30, 2019
	Common Stock			Capital Surplus, Paid In				Retained Earnings			Accumulated Other Comprehensive Loss				Total Common Stockholder's Equity			Common Stock				Capital Surplus, Paid In		Retained Earnings			Accumulated Other Comprehensive Loss			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount					Stock							Amount
Balance as of January 1, 2018	301	$	—				$		843,134		$	511,382					$	(3,922	)	$	1,350,594
Balance as of January 1, 2019																		301		$	0	$	678,134	$	627,258		$	(2,851	)	$	1,302,541
Net Income								35,093							35,093									32,781						32,781
Dividends on Common Stock																								(19,000		)				(19,000		)
Other Comprehensive Income											269				269												307			307
Balance as of March 31, 2018	301	—		843,134				546,475			(3,653		)		1,385,956
Balance as of March 31, 2019																		301		0		678,134		641,039			(2,544		)	1,316,629
Net Income								25,779							25,779									26,852						26,852
Capital Contributions from Eversource Parent				225,000											225,000
Return of Capital				(530,000		)									(530,000		)
Other								(1		)					(1		)
Dividends on Common Stock																								(214,000		)				(214,000		)
Other Comprehensive Income											269				269												296			296
Balance as of June 30, 2018	301	—		538,134				572,253			(3,384		)		1,107,003
Balance as of June 30, 2019																		301		0		678,134		453,891			(2,248		)	1,129,777
Net Income								40,666							40,666									40,879						40,879
Dividends on Common Stock																								(19,000		)				(19,000		)
Other Comprehensive Income											261				261												278			278
Balance as of September 30, 2018	301	$	—	$	538,134			$	612,919		$	(3,123	)		$	1,147,930
Balance as of September 30, 2019																		301		$	0	$	678,134	$	475,770		$	(1,970	)	$	1,151,934

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

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	For the Nine Months Ended September 30,						For the Nine Months Ended September 30,
(Thousands of Dollars)	2019			2018			2020			2019

Operating Activities:
Net Income	$	100,512		$	101,537		$	118,384		$	100,512
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	69,720			69,524			74,494			69,720
Deferred Income Taxes	12,960			11,473			13,959			12,960
Uncollectible Expense	4,977			4,865			2,058			4,977
Regulatory Underrecoveries, Net	(13,347		)	(19,764		)	(22,203		)	(13,347		)
Amortization of Regulatory Assets, Net	39,944			41,318			39,034			39,944
Pension, SERP and PBOP Expense	683			1,106
Pension, SERP and PBOP (Income)/Expense, Net							(894		)	683
Pension Contributions	(15,400		)	—			(19,500		)	(15,400		)
Other	(23,865		)	(9,075		)	(7,545		)	(23,865		)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(13,498		)	(32,819		)	(24,562		)	(13,498		)
Materials, Supplies and REC Inventory	13,545			14,555			(301		)	13,545
Taxes Receivable/Accrued, Net	31,909			10,929			1,313			31,909
Accounts Payable	(12,100		)	(3,828		)	(29,388		)	(12,100		)
Other Current Assets and Liabilities, Net	6,754			27,844			4,363			6,754
Net Cash Flows Provided by Operating Activities	202,794			217,665			149,212			202,794

Investing Activities:
Investments in Property, Plant and Equipment	(209,031		)	(236,206		)	(248,899		)	(209,031		)
Proceeds from the Sale of Generation Assets	—			193,924
Other Investing Activities	904			5,149			1,969			904
Net Cash Flows Used in Investing Activities	(208,127		)	(37,133		)	(246,930		)	(208,127		)

Financing Activities:
Cash Dividends on Common Stock	(252,000		)	(150,000		)	(22,300		)	(252,000		)
Capital Contributions from Eversource Parent	—			225,000
Return of Capital	—			(530,000		)
Issuance of Long-Term Debt	300,000			—			150,000			300,000
Retirement of Long-Term Debt	—			(110,000		)
Issuance of Rate Reduction Bonds	—			635,663
Repayment of Rate Reduction Bonds	(52,332		)	—			(43,210		)	(52,332		)
Decrease in Notes Payable to Eversource Parent	(14,900		)	(216,300		)
Increase/(Decrease) in Notes Payable to Eversource Parent							2,100			(14,900		)
Other Financing Activities	(4,146		)	1,080			(2,965		)	(4,146		)
Net Cash Flows Used in Financing Activities	(23,378		)	(144,557		)
Net (Decrease)/Increase in Cash and Restricted Cash	(28,711		)	35,975
Net Cash Flows Provided by/(Used in) Financing Activities							83,625			(23,378		)
Net Decrease in Cash and Restricted Cash							(14,093		)	(28,711		)
Cash and Restricted Cash - Beginning of Period	52,723			2,191			36,688			52,723
Cash and Restricted Cash - End of Period	$	24,012		$	38,166		$	22,595		$	24,012

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

EVERSOURCE ENERGY AND SUBSIDIARIES

THE CONNECTICUT LIGHT AND POWER COMPANY

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

COMBINED NOTES TO CONDENSED FINANCIAL STATEMENTS (Unaudited)

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

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

A. Basis of Presentation

Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business. Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), Yankee Gas, ~~and~~ NSTAR Gas and Eversource Gas Company of Massachusetts (natural gas utilities) and Aquarion (water utilities). Eversource provides energy delivery and/or water service to approximately ~~4000000~~4.3 million electric, natural gas and water customers through 89 regulated utilities in Connecticut, Massachusetts and New Hampshire.

On October 9, 2020, Eversource completed the acquisition of certain assets that comprised NiSource’s local natural gas distribution business in Massachusetts, which was previously doing business as Columbia Gas of Massachusetts (CMA). The natural gas distribution assets acquired from CMA were assigned to Eversource Gas Company of Massachusetts, an indirect wholly-owned subsidiary of Eversource formed in 2020. The LNG assets acquired from CMA were assigned to Hopkinton LNG Corp. The cash purchase price was $1.1 billion plus a target working capital amount, which is subject to adjustment to reflect actual working capital as of the closing date. See Note 17, "Acquisition of Assets of Columbia Gas of Massachusetts," for further information.

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 are herein collectively referred to as the "financial statements."

The combined notes to the financial statements have been prepared pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures included in annual financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations. The accompanying financial statements should be read in conjunction with the Combined Notes to Financial Statements included in Item 8, "Financial Statements and Supplementary Data," of the Eversource ~~2018~~2019 Form 10-K, which was filed with the SEC on February ~~26, 2019.~~27, 2020. The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

The financial statements contain, in the opinion of management, all adjustments (including normal, recurring adjustments) necessary to present fairly Eversource's, CL&P's, NSTAR Electric's and PSNH's financial position as of September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, and the results of operations, comprehensive income and common shareholders' equity for the three and nine months ended September 30, ~~2019~~2020 and ~~2018,~~2019, and the cash flows for the nine months ended September 30, ~~2019~~2020 and ~~2018.~~2019. The results of operations and comprehensive income for the three and nine months ended September 30, ~~2019~~2020 and ~~2018~~2019 and the cash flows for the nine months ended September 30, ~~2019~~2020 and ~~2018~~2019 are not necessarily indicative of the results expected for a full year.

Eversource consolidates the operations of CYAPC and YAEC, both of which are inactive regional nuclear power companies engaged in the long-term storage of their spent nuclear fuel. Eversource consolidates CYAPC and YAEC because CL&P's, NSTAR Electric's and PSNH's combined ownership and voting interests in each of these entities is greater than 50 percent. Intercompany transactions between CL&P, NSTAR Electric, PSNH and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.

Eversource holds several equity ownership interests that are not consolidated and are accounted for under the equity method.

Eversource's utility subsidiaries' electric, natural gas and water distribution 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.

COVID-19 has adversely affected workers and the economy and caused volatility in the financial markets. Due to the inherent uncertainty of the unprecedented and evolving situation, we continue to closely monitor how COVID-19 related developments affect Eversource. As of the date of our filing and based on available information, we have not experienced significant impacts directly related to the pandemic that have adversely affected our current operations, financial position, results of operations, and cash flows. The extent of the impact to us in the future will vary and depend in large part on the duration, scope and severity of the pandemic and the timing and extent of COVID-19 relief legislation, and the resulting impact on economic, health care and capital market conditions. The future impact will also depend on the outcome of planned proceedings before our state regulatory commissions to recover our incremental costs associated with COVID-19.

We believe that we have in place, or are developing, successful mechanisms with our state regulatory commissions that allow, or will allow, us to recover our incremental costs associated with COVID-19, which include uncollectible customer receivable expenses, while balancing the impact on our customers’ bills and our operating cash flows. See Note 1C, "Summary of Significant Accounting Policies - Allowance for Uncollectible Accounts," for discussion of our evaluation of the allowance for doubtful accounts as of September 30, 2020 in light of the COVID-19 pandemic.

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 ~~June 2016,~~December 2019, the FASB issued Accounting Standards Update ~~(“ASU”)~~(ASU) 2019-12, Income Taxes (Topic 740) - Simplifying the Accounting for Income Taxes, which eliminates certain exceptions to the general principles of current income tax guidance in ASC 740 and simplifies and improves consistency in application of that income tax guidance through clarifications of and amendments to ASC 740. The guidance is effective in the first quarter of 2021. The ASU is not expected to have a material impact on the financial statements of Eversource, CL&P, NSTAR Electric and PSNH.

Accounting Standards Recently Adopted: On January 1, 2020, the Company adopted ASU 2016-13, Financial Instruments - Credit Losses (Topic 326), which provides a ~~new~~ model for recognizing credit losses on financial instruments based on an estimate of current expected ~~credit losses. Under the new guidance,~~losses, requiring immediate recognition of ~~all~~ credit losses expected over the life of a financial ~~instrument is required. The standard is effective January 1, 2020 and requires a modified retrospective method through a cumulative effect adjustment to retained earnings.~~instrument. The Company ~~is assessing~~determined the impacts of this standard on the ~~accounting~~allowance for credit losses on its financial instruments, ~~including~~primarily accounts ~~receivable, and does not expect it to have a material impact on the financial statements.~~

~~Accounting Standards Recently Adopted:~~ ~~On January 1, 2019, the Company adopted ASU 2016-02,~~ ~~Leases (Topic 842),~~ ~~which amended existing lease accounting guidance. The Company applied the Topic 842 lease criteria to new leases and lease renewals entered into effective on or after January 1, 2019.~~ The ASU required balance sheet recognition of leases deemed to be operating leases as well as additional disclosure requirements. The recognition, measurement and presentation of expenses and cash flows were not significantly changed.

~~The Company also adopted the modified retrospective transition method allowed in ASU 2018-11,~~ ~~Leases (Topic 842) - Targeted Improvements, which allowed the Company to adopt the new leases standard as~~receivable. As of January 1, ~~2019, with prior periods presented in~~2020, the ~~financial statements continuing~~Company recorded increases to ~~follow existing lease accounting guidance under Topic 840 (Leases) in~~ the ~~accounting literature. Implementation~~allowance for uncollectible accounts for late fees and other receivable amounts of ~~ASU 2018-11 had no effect on retained earnings,~~$1.6 million, $0.9 million, $0.2 million and ~~the requirements of the new lease standard (Topic 842) are reflected in the 2019 financial statements and footnotes.~~

The Company elected the practical expedient package whereby it did not need to reassess whether or not an existing contract is or contains a lease or whether a lease is an operating or capital lease, and it did not need to reassess initial direct costs for leases. Election of this practical expedient allowed us to carry forward our historical lease classifications. The Company elected the practical expedient to not reevaluate land easements existing at adoption if they were not previously accounted for as leases. The Company also elected to use the discount rate as of the January 1, 2019 implementation date to discount its operating lease liabilities. The Company did not elect the hindsight practical expedient to determine the lease term for existing leases.

The Company determined the impact the ASUs had on its financial statements by reviewing its lease population and identifying lease data needed for the disclosure requirements. The Company implemented a new lease accounting system in 2019 to ensure ongoing compliance with the ASU’s requirements. Adoption of the new standard resulted in the recording of operating lease liabilities and right-of-use assets on the balance sheet upon transition at January 1, 2019 of $58.0$0.3 million at Eversource, ~~$25.3 million at NSTAR Electric, $0.6 million at CL&P, and $0.6 million at PSNH. Implementation of the new guidance did not have an impact on each company’s results of operations or cash flows.~~

~~C. Impairment of Northern Pass Transmission~~

Northern Pass was Eversource's planned 1,090 MW HVDC transmission line that would interconnect from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. As a result of a final decision received on July 19, 2019 from the New Hampshire Supreme Court, whereby the court issued a decision denying Northern Pass’ appeal and affirming the NHSEC’s evaluation and decision that denied Northern Pass’ siting application on NPT, Eversource concluded that construction of NPT was no longer probable. As a result, substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired.

Based on the conclusion that the construction of Northern Pass was not probable, Eversource recorded an impairment charge in the second quarter of 2019 for all of the project costs associated with Northern Pass, which were primarily engineering design, siting, permitting and legal costs, along with appropriate allowances for funds used during construction, and recognized a receivable for certain cost reimbursement agreements. Additionally, Eversource recorded an impairment charge associated with the land acquired to construct Northern Pass in order to recognize the land at its estimated fair value based on assessed values and transaction costs. In total, this resulted in a pre-tax impairment charge of $239.6 million within Operating Income on the statement of income for the nine months ended September 30, 2019, and was reflected in the Electric Transmission segment. The after-tax impact of the second quarter impairment charge was $204.4 million, or $0.64 per share, after giving effect to the estimated fair value of the related land, reimbursement agreements, and the impact of expected income tax benefits associated with the impairment charge. Eversource does not expect any significant estimated future cash expenditures associated with this impairment charge.

~~D. Provision for Uncollectible Accounts~~

~~Eversource, including~~ CL&P, NSTAR Electric and PSNH, ~~presents~~respectively. The impact to retained earnings, net of tax, was $1.5 million, $0.9 million, $0.2 million and $0.3 million at Eversource, CL&P, NSTAR Electric and PSNH, respectively.

The Company also adjusted the allowance for uncollectible amounts of hardship receivables and other low-income assistance programs, which are ultimately collectible in rates at specified points in time under approved regulatory mechanisms. The impact on the allowance, which was offset in other long-term assets on the balance sheets, was an increase of $22.2 million and $21.3 million at Eversource and CL&P, respectively, and a decrease of $1.5 million at NSTAR Electric. See Note 1C, “Summary of Significant Accounting Policies - Allowance for Uncollectible Accounts,” for further information.

The Company adopted ASU 2017-04, Intangibles - Goodwill and Other (Topic 350), Simplifying the Test for Goodwill Impairment as of January 1, 2020. The ASU simplified the accounting for goodwill impairment by removing a complex step in the goodwill impairment test. Under the guidance, goodwill impairment is measured as the amount by which its carrying value exceeds its fair value. The ASU is not expected to have an impact on the financial statements of Eversource.

On January 1, 2020, the Company adopted ASU 2018-15, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40) - Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service Contract. The ASU aligned the requirements for capitalizing costs incurred to implement a cloud computing arrangement with existing internal-use software guidance. The prospective implementation of this standard did not have any impact on the financial statements of Eversource, CL&P, NSTAR Electric or PSNH for the period ending September 30, 2020.

On January 1, 2020, the Company prospectively adopted ASU 2018-13, Fair Value Measurement (Topic 820), Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement. The ASU modified fair value disclosure requirements. The standard includes new disclosure requirements for Level 3 unobservable inputs and eliminated the requirement to disclose certain information relating to transfers between levels. The modified disclosures are included in Note 1D, “Summary of Significant Accounting Policies - Fair Value Measurements,” and Note 4, “Derivative Instruments.”

C. Allowance for Uncollectible Accounts

Receivables, Net on the balance sheets primarily includes trade receivables from retail customers and customers related to wholesale transmission contracts, wholesale market sales, sales of RECs and property rentals. Receivables, Net also includes customer receivables for the purchase of electricity from a competitive third party supplier, the current portion of customer energy efficiency loans, property damage receivables and other miscellaneous receivables. There is no material concentration of receivables. Receivables are recorded at amortized cost, net of a credit loss provision (or allowance for uncollectible accounts).

Receivables are presented net of expected credit losses at estimated net realizable value by maintaining ~~a provision~~an allowance for uncollectible accounts. Effective January 1, 2020, the current expected credit loss (CECL) model was applied to receivables for purposes of calculating the allowance for uncollectible accounts. This ~~provision~~model is based on expected losses and results in the recognition of estimated expected credit losses, including uncollectible amounts for both billed and unbilled revenues, over the life of the receivable at the time a receivable is recorded.

The allowance for uncollectible accounts 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~~Factors in determining credit loss include historical collection, ~~and~~ write-off experience, and management's assessment of ~~collectability~~collectibility from ~~customers.~~customers, including current conditions, reasonable forecasts, and expectations of future collectibility and collection efforts. Management continuously assesses the ~~collectability~~collectibility of receivables and adjusts ~~collectability~~ estimates based on actual ~~experience.~~experience and future expectations based on economic indicators, collection efforts and other factors. Management also monitors the aging analysis of receivables to determine if there are changes in the collections of accounts receivable. Receivable balances are written off against the ~~provision~~allowance for uncollectible accounts when the customer accounts are ~~terminated~~no longer in service and these balances are deemed to be uncollectible.

As of September 30, 2020, management evaluated the adequacy of the allowance for uncollectible accounts in light of the COVID-19 pandemic and the related economic downturn. This evaluation included an analysis of collection and customer payment trends in 2020, economic conditions, flexible payment plans and financial hardship arrearage management programs being offered to customers, and the impacts of federal governmental pandemic relief programs for our customers and the expansion of unemployment benefit initiatives, which help to mitigate the potential for increasing customer account delinquencies. Additionally, management considered past economic declines and corresponding uncollectible reserves as part of the current assessment. This evaluation has shown that our operating companies have experienced an increase in aged receivables and some lower cash collections from customers because of the moratorium on disconnections and the economic slowdown resulting from the COVID-19 pandemic. Based upon the evaluation performed, for the three and nine months ended September 30, 2020, management increased the allowance for uncollectible costs incurred as a result of COVID-19 by $11.3 million and $16.5 million for Eversource, respectively ($2.8 million for CL&P for both periods, $5.1 million for NSTAR Electric for both periods, and $1.5 million for PSNH for both periods). These COVID-19 related uncollectible amounts were deferred either as incremental regulatory costs or deferred through existing regulatory tracking mechanisms that recover uncollectible energy supply costs as management believes it is probable that these costs will ultimately be recovered from customers in rates.

Management concluded that the reserve balance as of September 30, 2020 adequately reflected the collection risk and net realizable value for Eversource’s receivables. Management will continue to evaluate the adequacy of the uncollectible allowance in future reporting periods based on an ongoing assessment of accounts receivable collections, delinquency statistics, and analysis of aging-based quantitative assessments.

The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively. The DPU allows NSTAR Electric and NSTAR Gas to recover in rates amounts associated with certain uncollectible hardship accounts receivable. These uncollectible hardship customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets. Hardship customers are protected from shut-off in certain circumstances, and historical collection experience has reflected a higher default risk as compared to the rest of the receivable population. As a result of the adoption of ASU 2016-13, management aligned the allowance for uncollectible hardship accounts across all regulatory jurisdictions, using a higher credit risk profile for this pool of trade receivables as compared to non-hardship receivables. Implementation impacts of the accounting standard on the allowance for uncollectible hardship accounts are reflected in the rollforward of the uncollectible allowance in the table below. The allowance for uncollectible hardship accounts is included in the total uncollectible allowance balance.

The total ~~provision~~allowance for uncollectible accounts is included in Receivables, Net on the balance sheets. The ~~provision~~activity in the allowance for uncollectible ~~hardship~~ accounts by portfolio segment is ~~included in the total uncollectible provision balance. The provision balances are~~ as follows:

Total Provision for Uncollectible Accounts Provision for Uncollectible Hardship Accounts
(Millions of Dollars) As of September 30, 2019 As of December 31, 2018 As of September 30, 2019 As of December 31, 2018
Eversource $ 225.5
$ 212.7
$ 146.5
$ 131.5
CL&P 94.1
88.0
77.8
71.9
NSTAR Electric 80.7
74.5
49.4
42.5
PSNH 10.6
11.1
—
—



	Eversource									CL&P									NSTAR Electric									PSNH
(Millions of Dollars)	Hardship Accounts			Retail (Non-Hardship), Wholesale, and Other Receivables			Total Allowance			Hardship Accounts			Retail (Non-Hardship), Wholesale and Other Receivables			Total Allowance			Hardship Accounts			Retail (Non-Hardship), Wholesale, and Other Receivables			Total Allowance			Total Allowance
Three Months Ended
Beginning Balance	$	175.5		$	94.5		$	270.0		$	116.3		$	20.4		$	136.7		$	34.6		$	34.1		$	68.7		$	11.8
Uncollectible Expense ⁽¹⁾	0			10.5			10.5			0			3.8			3.8			0			4.5			4.5			0.8
Uncollectible Costs Deferred ⁽²⁾	10.1			20.4			30.5			11.2			4.9			16.1			(1.3		)	10.4			9.1			3.2
Write-Offs	(7.3		)	(11.8		)	(19.1		)	(2.6		)	(4.6		)	(7.2		)	(0.2		)	(6.3		)	(6.5		)	(2.0		)
Recoveries Collected	0.4			2.7			3.1			0.3			1.1			1.4			0			1.0			1.0			0.2
Ending Balance	$	178.7		$	116.3		$	295.0		$	125.2		$	25.6		$	150.8		$	33.1		$	43.7		$	76.8		$	14.0

Nine Months Ended
Beginning Balance	$	143.3		$	81.5		$	224.8		$	80.1		$	17.2		$	97.3		$	43.9		$	31.5		$	75.4		$	10.5
ASU 2016-13 Implementation Impact on January 1, 2020	21.6			2.2			23.8			21.3			0.9			22.2			(1.6		)	0.3			(1.3		)	0.3
Uncollectible Expense ⁽¹⁾	0			31.1			31.1			0			10.0			10.0			0			11.3			11.3			2.1
Uncollectible Costs Deferred ⁽²⁾	24.9			41.5			66.4			32.7			8.3			41.0			(8.4		)	17.3			8.9			5.6
Write-Offs	(12.3		)	(49.3		)	(61.6		)	(10.0		)	(14.0		)	(24.0		)	(0.8		)	(20.5		)	(21.3		)	(5.0		)
Recoveries Collected	1.2			9.3			10.5			1.1			3.2			4.3			0			3.8			3.8			0.5
Ending Balance	$	178.7		$	116.3		$	295.0		$	125.2		$	25.6		$	150.8		$	33.1		$	43.7		$	76.8		$	14.0

⁽¹⁾Uncollectible expense associated with ~~customers'~~customer and other accounts receivable is included in Operations and Maintenance expense on the statements of ~~income is as follows:~~

For the Three Months Ended For the Nine Months Ended
(Millions of Dollars) September 30, 2019 September 30, 2018 September 30, 2019 September 30, 2018
Eversource $ 14.9
$ 21.5
$ 46.4
$ 50.7
CL&P 4.5
4.4
12.1
12.1
NSTAR Electric 7.0
9.1
18.6
20.4
PSNH 1.8
1.6
5.0
4.9

income. For the three and nine months ended September 30, 2019, uncollectible expense included in Operations and Maintenance Expense was $14.9 million and $46.4 million for Eversource, $4.5 million and $12.1 million for CL&P, $7.0 million and $18.6 million for NSTAR Electric and $1.8 million and $5.0 million for PSNH, respectively.

E.⁽²⁾The current period provision for expected credit losses is deferred as a regulatory cost on the balance sheets, as this amount is ultimately recovered in rates. Amounts include uncollectible costs for hardship accounts and other customer receivables, including uncollectible amounts related to COVID-19.

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")~~(normal) and to the marketable securities held in trusts. Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill, long-lived assets and AROs, and the estimated fair value of preferred stock, long-term debt and RRBs.

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.~~basis. 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.

Uncategorized - Investments that are measured at net asset value are not categorized within the fair value hierarchy.

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 ~~11,~~10, "Fair Value of Financial Instruments," to the financial statements.

~~F. Investments in Unconsolidated Affiliates~~

~~Investments in Offshore Wind Business:~~ Eversource's offshore wind business includes ownership interests in North East Offshore and Bay State Wind, which together hold power purchase agreements and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind projects. Eversource's offshore wind projects are being developed in joint and equal partnership with Ørsted.

On February 8, 2019, Eversource and Ørsted entered into an equal partnership to acquire key offshore wind assets in the Northeast, where Eversource owns 50 percent of these assets. Eversource's initial payment and contribution under the terms of the partnership agreements totaled approximately $225 million for a 50 percent ownership interest in North East Offshore, which holds the Revolution Wind and South Fork Wind projects, as well as a 257 square-mile lease off the coasts of Massachusetts and Rhode Island. Eversource also has a 50 percent ownership interest in Bay State Wind, which holds the Sunrise Wind project. These equity investments are included in long-term assets on the balance sheet, and earnings impacts are included in Other Income, Net on the statement of income. As of September 30, 2019, Eversource's total equity investment balance in its offshore wind business was $637.2 million. In the third quarter of 2019, Eversource made additional capital contributions of $133.6 million.

G.E. Other Income, Net

The components of Other Income, Net on the statements of income were as follows:



	For the Three Months Ended
	September 30, 2020										September 30, 2019
(Millions of Dollars)	Eversource			CL&P		NSTAR Electric			PSNH		Eversource			CL&P			NSTAR Electric			PSNH
Pension, SERP and PBOP Non-Service Income Components	$	11.0		$	0.9	$	7.2		$	1.8	$	10.1		$	1.7		$	5.6		$	1.4
AFUDC Equity	10.3			3.5		5.5			0.9		10.5			3.6			5.6			1.0
Equity in Earnings of Unconsolidated Affiliates ⁽¹⁾	3.9			0		0.1			0		6.1			0			0.2			0
Investment Income/(Loss)	1.0			1.3		(0.2		)	0.2		(2.8		)	(0.8		)	(0.9		)	(0.3		)
Interest Income	1.5			0.2		0.1			1.2		2.9			0.3			0.1			2.5
Gain on Sale of Property	1.5			0		0			0		0			0			0			0
Other	0			0		0.1			0		0.2			0			0.1			0
Total Other Income, Net	$	29.2		$	5.9	$	12.8		$	4.1	$	27.0		$	4.8		$	10.7		$	4.6

	For the Nine Months Ended
	September 30, 2020										September 30, 2019
(Millions of Dollars)	Eversource			CL&P		NSTAR Electric			PSNH		Eversource			CL&P			NSTAR Electric			PSNH
Pension, SERP and PBOP Non-Service Income Components	$	34.3		$	3.0	$	22.2		$	5.2	$	23.2		$	0.1		$	18.0		$	3.5
AFUDC Equity	31.8			11.4		15.8			3.5		34.5			9.4			14.7			2.1
Equity in Earnings of Unconsolidated Affiliates ⁽¹⁾	13.8			0		0.4			0		37.0			0.2			0.6			0
Investment (Loss)/Income	(1.5		)	0		(1.5		)	0.1		(2.3		)	0.9			(1.5		)	0
Interest Income	3.3			1.8		0.7			2.0		10.8			1.1			0.5			9.0
Gain on Sale of Property	1.8			0		0.3			0		0.2			0			0			0
Other	0.1			0.1		0.3			0.1		0.4			(0.1		)	0.2			0
Total Other Income, Net	$	83.6		$	16.3	$	38.2		$	10.9	$	103.8		$	11.6		$	32.5		$	14.6

For the Three Months Ended
September 30, 2019 September 30, 2018
(Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH
Pension, SERP and PBOP Non-Service
Income Components
$ 10.1
$ 1.7
$ 5.6
$ 1.4
$ 14.8
$ 2.0
$ 9.0
$ 2.0
AFUDC Equity 10.5
3.6
5.6
1.0
12.0
3.3
4.2
—
Equity in Earnings/(Loss) and Impairment of Unconsolidated Affiliates ⁽¹⁾
6.1
—
0.2
—
(27.9 ) —
0.2
—
Investment Income/(Loss) (2.8 ) (0.8 ) (0.9 ) (0.3 ) 1.8
0.7
(0.4 ) 0.1
Interest Income ⁽²⁾
2.9
0.3
0.1
2.5
10.8
0.9
0.2
9.6
Gain on Sale of Property —
—
—
—
5.0
—
0.5
4.4
Other 0.2
—
0.1
—
0.2
0.2
—
—
Total Other Income, Net $ 27.0
$ 4.8
$ 10.7
$ 4.6
$ 16.7
$ 7.1
$ 13.7
$ 16.1

For the Nine Months Ended
September 30, 2019 September 30, 2018
(Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH
Pension, SERP and PBOP Non-Service
Income Components
$ 23.2
$ 0.1
$ 18.0
$ 3.5
$ 44.6
$ 7.3
$ 26.8
$ 6.4
AFUDC Equity 34.5
9.4
14.7
2.1
32.6
9.4
11.5
—
Equity in Earnings/(Loss) and Impairment of Unconsolidated Affiliates ⁽¹⁾
37.0
0.2
0.6
—
(0.4 ) —
0.6
—
Investment Income/(Loss) (2.3 ) 0.9
(1.5 ) —
2.2
0.9
0.6
0.2
Interest Income ⁽²⁾
10.8
1.1
0.5
9.0
16.2
2.9
0.6
13.3
Gain on Sale of Property 0.2
—
—
—
5.0
—
0.5
4.4
Other 0.4
(0.1 ) 0.2
—
0.5
0.2
—
—
Total Other Income, Net $ 103.8
$ 11.6
$ 32.5
$ 14.6
$ 100.7
$ 20.7
$ 40.6
$ 24.3

⁽¹⁾For the three and nine months ended September 30, 2018, equity in earnings/(loss) and impairment of unconsolidated affiliates includes an other-than-temporary impairment of $32.9 million of the Access Northeast project investment.For the nine months ended September 30, 2019 and 2018, equity in earnings includes $20.4 million and $17.6 million, respectively, of unrealized gains associated with an investment in a renewable energy fund.

⁽²⁾For the nine months ended September 30, 2019, see Note 2, "Regulatory Accounting," for further information on $5.2 million of interest income recognized in 2019 for the equity return component of carrying charges on storm costs at PSNH. For the three and nine months ended September 30, 2018, PSNH recognized $8.7 million for the equity return component of carrying charges on storm costs incurred from August 2011 through March 2013.


⁽¹⁾	Equity in Earnings of Unconsolidated Affiliates includes $2.4 million of primarily realized gains associated with an investment in a renewable energy fund for the nine months ended September 30, 2020. For the nine months ended September 30, 2019, unrealized gains on this investment totaled $20.4 million.

H.F. Other Taxes

Eversource's companies that serve customers in Connecticut collect gross receipts taxes levied by the state of Connecticut from their customers. These gross receipts taxes are recorded separately with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the statements of income as follows:


	For the Three Months Ended				For the Nine Months Ended				For the Three Months Ended				For the Nine Months Ended
(Millions of Dollars)	September 30, 2019		September 30, 2018		September 30, 2019		September 30, 2018		September 30, 2020		September 30, 2019		September 30, 2020		September 30, 2019
Eversource	$	42.6	$	43.5	$	124.0	$	122.5	$	48.4	$	42.6	$	129.1	$	124.0
CL&P	39.8		40.6		107.8		107.7		45.6		39.8		114.2		107.8

Separate from above was an amount recorded as Taxes Other Than Income Taxes at CL&P related to the remittance to the State of Connecticut of energy efficiency funds collected from customers of $21.4 million for the nine months ended September 30, 2019. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. This amount was recorded separately, with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the Eversource and CL&P statements of income.

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

Separate from above were amounts recorded as Taxes Other Than Income Taxes related to the remittance to the State of Connecticut of energy efficiency funds collected from customers in Operating Revenues. These amounts were $21.4 million for the nine months ended September 30, 2019, and $10.7 million and $36.1 million for the three and nine months ended September 30, 2018, respectively. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. These amounts were recorded separately, with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the Eversource and CL&P statements of income.

I.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, 2019		As of September 30, 2018		As of September 30, 2020		As of September 30, 2019
Eversource	$	317.8	$	303.7	$	357.4	$	317.8
CL&P	107.6		103.0		97.8		107.6
NSTAR Electric	79.0		62.5		92.6		79.0
PSNH	35.8		48.3		50.0		35.8

Beginning in 2019, Eversource began issuing treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan. The issuance of treasury shares represents a non-cash transaction, as the treasury shares were used to fulfill Eversource's obligations that require the issuance of common shares.

The following table reconciles cash and cash equivalents as reported on the balance sheets to the cash, cash equivalents and restricted cash balance as reported on the statements of cash flows:


	As of September 30, 2019								As of December 31, 2018								As of September 30, 2020								As of December 31, 2019
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Cash as reported on the Balance Sheets	$	22.7	$	9.3	$	0.3	$	1.6	$	108.1	$	87.7	$	1.6	$	1.4
Cash and Cash Equivalents as reported on the Balance Sheets																	$	730.0	$	8.2	$	0.1	$	0.8	$	15.4	$	0	$	0.1	$	0.4
Restricted cash included in:
Prepayments and Other Current Assets	37.7		4.6		6.1		18.5		72.1		3.5		13.0		47.5
Special Deposits																	51.3		8.6		12.2		19.1		52.5		4.6		6.2		32.5
Marketable Securities	19.6		0.4		0.1		0.7		25.9		0.4		0.1		0.6		45.6		0.4		0.1		0.6		46.0		0.4		0		0.6
Other Long-Term Assets	71.9		—		—		3.2		3.2		—		—		3.2		2.1		0		0		2.1		3.2		0		0		3.2
Cash and Restricted Cash reported on the Statements of Cash Flows	$	151.9	$	14.3	$	6.5	$	24.0	$	209.3	$	91.6	$	14.7	$	52.7
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows																	$	829.0	$	17.2	$	12.4	$	22.6	$	117.1	$	5.0	$	6.3	$	36.7

~~Restricted cash included in Prepayments and Other Current Assets primarily represents~~Special Deposits represent cash collections related to the PSNH RRB customer charges that are held in trust, ~~and~~ required ISO-NE cash ~~deposits.~~deposits, and CYAPC and YAEC cash balances. Special Deposits are included in Current Assets on the balance sheets. Restricted cash included in Marketable Securities represents money market funds held in trusts to fund certain non-qualified executive benefits and restricted trusts to fund CYAPC and YAEC's spent nuclear fuel storage ~~facilities~~ obligations. Restricted cash included in Other Long-Term Assets at Eversource primarily relates to DOE Phase IV damages proceeds received at CYAPC and YAEC in the second quarter of 2019. See Note 9D, "Commitments and Contingencies - Spent Nuclear Fuel Obligations - Yankee Companies," for further information.

2. REGULATORY ACCOUNTING

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

The application of accounting guidance for rate-regulated enterprises results in recording regulatory assets and liabilities. Regulatory assets represent the deferral of incurred costs that are probable of future recovery in customer rates. Regulatory assets are amortized as the incurred costs are recovered through customer rates. Regulatory liabilities represent either revenues received from customers to fund expected costs that have not yet been incurred or probable future refunds to customers.

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

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


	As of September 30, 2019								As of December 31, 2018								As of September 30, 2020								As of December 31, 2019
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Benefit Costs	$	1,835.1	$	400.5	$	542.8	$	148.5	$	1,914.8	$	424.7	$	544.4	$	169.6	$	2,256.1	$	483.3	$	601.4	$	205.7	$	2,382.9	$	539.0	$	629.8	$	218.2
Income Taxes, Net	713.4		460.2		108.6		11.4		728.6		454.4		105.9		8.3		731.2		459.8		110.0		13.7		725.8		458.8		108.0		12.8
Securitized Stranded Costs	576.1		—		—		576.1		608.4		—		—		608.4		532.9		0		0		532.9		565.3		0		0		565.3
Storm Restoration Costs, Net	508.9		258.9		190.2		59.8		576.0		302.6		212.9		60.5		739.6		510.7		171.4		57.5		540.6		274.6		200.6		65.4
Regulatory Tracker Mechanisms	282.7		56.5		121.1		58.1		316.0		33.2		169.1		67.3		531.8		174.4		203.0		82.3		411.5		78.3		207.1		65.8
Derivative Liabilities	345.8		342.3		—		—		356.5		356.5		—		—		311.8		311.8		0		0		334.5		329.2		0		0
Goodwill-related	335.7		—		288.3		—		348.4		—		299.1		—		318.9		0		273.8		0		331.5		0		284.6		0
Asset Retirement Obligations	101.3		33.8		51.7		3.5		89.2		32.3		42.2		3.3		105.8		32.3		56.2		3.8		97.2		30.8		50.3		3.6
Other Regulatory Assets	131.8		25.6		57.6		13.0		208.0		27.0		64.6		12.1		118.0		34.2		56.9		16.5		125.4		25.2		55.2		14.7
Total Regulatory Assets	4,830.8		1,577.8		1,360.3		870.4		5,145.9		1,630.7		1,438.2		929.5		5,646.1		2,006.5		1,472.7		912.4		5,514.7		1,735.9		1,535.6		945.8
Less: Current Portion	538.2		173.3		201.2		78.1		514.8		125.2		241.7		67.2		762.9		273.8		278.6		103.6		651.1		178.6		285.6		84.1
Total Long-Term Regulatory Assets	$	4,292.6	$	1,404.5	$	1,159.1	$	792.3	$	4,631.1	$	1,505.5	$	1,196.5	$	862.3	$	4,883.2	$	1,732.7	$	1,194.1	$	808.8	$	4,863.6	$	1,557.3	$	1,250.0	$	861.7

Storm ~~Filings:~~Event: On ~~November 16, 2018,~~August 4, 2020, Tropical Storm Isaias caused catastrophic damage to our electric distribution system, which resulted in significant amounts and durations of customer outages, primarily in Connecticut. In terms of customer outages, this storm was one of the worst in CL&P’s history. PURA has opened an investigation into CL&P's response to Tropical Storm Isaias. PURA will also investigate the prudence of costs incurred by CL&P to restore service as part of its response. CL&P is fully participating in PURA’s investigations and believes that these storm restoration costs were prudently incurred and meet the criteria for cost recovery. As a result, management does not expect the storm costs to have a material impact on the results of operations of Eversource or CL&P.

Based on current estimates, the storm resulted in deferred storm restoration costs of approximately $257 million at CL&P and $276 million at Eversource as of September 30, 2020. The estimated cost of restoration will change as additional cost information becomes available and final storm costs are deferred or capitalized. The majority of incremental storm costs relate to third-party vendors that are external field crews needed to restore power and address municipal priorities. CL&P’s current estimate of total storm costs includes its projection of the cost of such vendors, but that estimate will change as CL&P receives and examines all storm related invoices. On October 12, 2020, CL&P filed ~~for recovery~~a motion requesting an extension of ~~$153 million of~~time to submit a final and complete report on storm costs ~~incurred from~~to PURA by July 1, 2021. On October ~~2017 through May 2018, with recovery over six years~~23, 2020, PURA denied this request, and on November 2, 2020, CL&P filed a request for reconsideration of PURA’s ruling.

CL&P Rate Suspension: On July 31, 2020, PURA temporarily suspended its June 26, 2020 approval of certain delivery rate components effective July 1, 2020, and ordered CL&P to ~~begin May~~restore rates to those in effect as of June 30, 2020 in order to allow PURA time to reexamine the rates to ensure that CL&P is not over-collecting revenues in the short-term. Rates were adjusted effective August 1, ~~2019. Through~~2020. PURA indicated that this was due to the ~~course~~convergence of a number of recent events, including the COVID-19 crisis and its corresponding effect on customer energy usage, as well as the warmer than normal weather in July. The impact of the ~~proceeding, CL&P updated its request to $145.5 million to reflect final invoicing and capitalization amounts. On April 17, 2019, PURA authorized recovery~~temporary suspension of ~~$141.0 million as part of storm cost recovery and the remainder to be recorded to plant or other~~rates is deferred on our balance sheet ~~accounts. CL&P began recovery of the $141.0 million~~and results in ~~distribution rates effective May 1, 2019.~~

On March 26, 2019, the NHPUC approved the recovery of $38.1 million, plus carrying charges, of storm costs incurred from December 2013 through April 2016 and the transfer of funding from PSNH’s major storm reservean increase to ~~recover those costs. The costs of these storms (excluding the equity return component of the carrying charges) were deferred as~~our regulatory assets, and the funding reserve collected from customers was accrued as a regulatory liability. As a result of the duration of time between incurring storm costs in December 2013 through April 2016 and final approval from the NHPUC in 2019, PSNH recognized $5.2 million (pre-tax) for the equity return component of the carrying charges within Other Income, Netwith no impact on the statement of income, and an expected delay in the ~~first quarter~~collection of ~~2019, which has been collected from customers. Also included~~our costs. This deferral is reflected within Regulatory Tracker Mechanisms in the ~~March 26, 2019 NHPUC approval is a prospective requirement for PSNH to annually net its storm funding reserve collected from customers against deferred storm costs.~~

In addition, on June 27, 2019, the NHPUC approved a temporary rate settlement that permits PSNH to recover approximately $68.5 million in unrecovered storm costs over a five-year period beginning August 1, 2019, with debt carrying charges.table above.

Regulatory Costs in Long-Term Assets: Eversource's regulated companies had ~~$144.3~~$183.9 million (including ~~$44.7~~$84.2 million for CL&P, ~~$61.5~~$55.0 million for NSTAR Electric and ~~$17.8~~$15.3 million for PSNH) and ~~$122.9~~$146.0 million (including ~~$42.1~~$51.8 million for CL&P, ~~$49.3~~$55.7 million for NSTAR Electric and ~~$12.2~~$18.0 million for PSNH) of additional regulatory costs as of September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively, that were included in long-term assets on the balance sheets. These amounts represent incurred costs for which recovery has not yet been specifically approved by the applicable regulatory agency. However, based on regulatory policies or past precedent on similar costs, management believes it is probable that these costs will ultimately be approved and recovered from customers in rates. As of September 30, 2020, net incremental COVID-19 related costs deferred by Eversource totaled $15.1 million, of which $11.4 million was related to uncollectible expense.

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


	As of September 30, 2019								As of December 31, 2018								As of September 30, 2020								As of December 31, 2019
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
EDIT due to Tax Cuts and Jobs Act	$	2,846.9	$	1,025.7	$	1,083.2	$	394.0	$	2,883.0	$	1,031.0	$	1,103.7	$	396.4	$	2,805.3	$	1,013.9	$	1,050.1	$	388.7	$	2,844.6	$	1,022.8	$	1,071.2	$	392.8
Cost of Removal	552.0		56.3		325.2		20.5		521.0		39.9		307.1		22.1		610.4		93.0		354.8		12.9		559.8		64.6		330.6		16.3
Benefit Costs	79.7		—		67.4		—		91.2		—		76.9		—		79.5		0		68.7		0		84.5		0		72.2		0
Regulatory Tracker Mechanisms	404.3		169.7		167.9		43.3		309.0		89.5		163.7		48.3		445.7		171.1		181.9		56.2		325.1		94.8		165.6		57.0
AFUDC - Transmission	72.6		46.4		26.2		—		70.7		47.4		23.3		—		77.1		45.0		32.1		0		73.2		46.0		27.2		0
Revenue Subject to Refund due to Tax Cuts and Jobs Act	18.3		—		—		9.0		24.6		—		—		12.6
Other Regulatory Liabilities	111.9		29.9		49.1		6.0		80.2		24.0		29.2		4.2		158.2		38.2		57.9		9.9		132.0		19.6		59.0		13.1
Total Regulatory Liabilities	4,085.7		1,328.0		1,719.0		472.8		3,979.7		1,231.8		1,703.9		483.6		4,176.2		1,361.2		1,745.5		467.7		4,019.2		1,247.8		1,725.8		479.2
Less: Current Portion	441.2		168.1		199.4		54.7		370.2		109.6		190.6		55.5		464.7		164.9		210.7		61.5		361.2		82.8		209.2		65.8
Total Long-Term Regulatory Liabilities	$	3,644.5	$	1,159.9	$	1,519.6	$	418.1	$	3,609.5	$	1,122.2	$	1,513.3	$	428.1	$	3,711.5	$	1,196.3	$	1,534.8	$	406.2	$	3,658.0	$	1,165.0	$	1,516.6	$	413.4

3. PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

The following tables summarize property, plant and equipment by asset category:


Eversource	As of September 30, 2019			As of December 31, 2018			As of September 30, 2020			As of December 31, 2019
(Millions of Dollars)
Distribution - Electric	$	15,737.6		$	15,071.1		$	16,435.4		$	15,880.0
Distribution - Natural Gas	3,723.7			3,546.2			4,073.0			3,931.1
Transmission - Electric	10,570.6			10,153.9			11,601.7			10,958.4
Distribution - Water	1,686.3			1,639.8			1,683.8			1,726.5
Solar	199.2			164.1			201.2			200.2
Utility	31,917.4			30,575.1			33,995.1			32,696.2
Other ⁽¹⁾	935.2			778.6			1,193.0			1,025.6
Property, Plant and Equipment, Gross	32,852.6			31,353.7			35,188.1			33,721.8
Less: Accumulated Depreciation
Utility	(7,417.6		)	(7,126.2		)	(7,731.0		)	(7,483.5		)
Other	(375.1		)	(336.7		)	(455.2		)	(387.4		)
Total Accumulated Depreciation	(7,792.7		)	(7,462.9		)	(8,186.2		)	(7,870.9		)
Property, Plant and Equipment, Net	25,059.9			23,890.8			27,001.9			25,850.9
Construction Work in Progress	1,852.0			1,719.6			2,091.1			1,734.6
Total Property, Plant and Equipment, Net	$	26,911.9		$	25,610.4		$	29,093.0		$	27,585.5


	As of September 30, 2019									As of December 31, 2018									As of September 30, 2020									As of December 31, 2019
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Distribution - Electric	$	6,417.9		$	7,102.3		$	2,257.7		$	6,176.4		$	6,756.4		$	2,178.6		$	6,728.7		$	7,414.0		$	2,332.9		$	6,485.5		$	7,163.7		$	2,271.1
Transmission - Electric	4,938.5			4,186.6			1,440.7			4,700.5			4,065.9			1,338.7			5,299.0			4,608.9			1,689.0			5,043.0			4,411.9			1,498.7
Solar	—			199.2			—			—			164.1			—			0			201.2			0			0			200.2			0
Property, Plant and Equipment, Gross	11,356.4			11,488.1			3,698.4			10,876.9			10,986.4			3,517.3			12,027.7			12,224.1			4,021.9			11,528.5			11,775.8			3,769.8
Less: Accumulated Depreciation	(2,370.6		)	(2,860.3		)	(803.0		)	(2,302.6		)	(2,702.0		)	(772.9		)	(2,453.1		)	(3,022.7		)	(832.8		)	(2,385.7		)	(2,895.3		)	(799.9		)
Property, Plant and Equipment, Net	8,985.8			8,627.8			2,895.4			8,574.3			8,284.4			2,744.4			9,574.6			9,201.4			3,189.1			9,142.8			8,880.5			2,969.9
Construction Work in Progress	470.8			636.4			136.6			335.4			510.3			135.7			490.7			742.0			130.4			483.0			592.3			159.6
Total Property, Plant and Equipment, Net	$	9,456.6		$	9,264.2		$	3,032.0		$	8,909.7		$	8,794.7		$	2,880.1		$	10,065.3		$	9,943.4		$	3,319.5		$	9,625.8		$	9,472.8		$	3,129.5


⁽¹⁾	These assets are primarily comprised of ~~building improvements,~~ computer software, hardware and equipment at Eversource ~~Service.~~Service and buildings at The Rocky River Realty Company.

InSale of Water System: On July 31, 2020, Eversource sold its water system and treatment plant that supplies water to the ~~second~~towns of Hingham, Hull and North Cohasset to the town of Hingham, Massachusetts. Net property, plant and equipment of $63.9 million and goodwill of $23.6 million were included in determining the gain on sale. Proceeds from the sale were $110.5 million, with a pre-tax gain of $16.0 million (after-tax gain of $3.5 million) recognized within Operations and Maintenance Expense on the statement of income in the third quarter of ~~2019, Eversource recorded an impairment charge for~~2020. The assets and liabilities associated with the ~~NPT project costs, which had been recorded within Construction Work~~sale of the business were previously reflected in ~~Progress~~the Water Distribution segment and also the Transmission - Electric asset category. For further information regarding the impairment of NPT, see Note 1C, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements.reporting unit.

4. DERIVATIVE INSTRUMENTS

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

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

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

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


		As of September 30, 2019									As of December 31, 2018										As of September 30, 2020									As of December 31, 2019
(Millions of Dollars)	Fair Value Hierarchy	Commodity Supply and Price Risk Management			Netting ⁽¹⁾			Net Amount Recorded as a Derivative			Commodity Supply and Price Risk Management			Netting ⁽¹⁾			Net Amount Recorded as a Derivative			Fair Value Hierarchy	Commodity Supply and Price Risk Management			Netting ⁽¹⁾			Net Amount Recorded as a Derivative			Commodity Supply and Price Risk Management			Netting ⁽¹⁾			Net Amount Recorded as a Derivative
Current Derivative Assets:
CL&P	Level 3	$	11.6		$	(0.3	)	$	11.3		$	9.6		$	(3.4	)	$	6.2		Level 3	$	13.5		$	(0.4	)	$	13.1		$	12.2		$	(0.4	)	$	11.8
Other	Level 2	—			—			—			1.5			(0.9		)	0.6			Level 2	3.4			(0.7		)	2.7			0			0			0
Long-Term Derivative Assets:
CL&P	Level 3	70.9			(2.2		)	68.7			74.2			(2.3		)	71.9			Level 3	59.1			(1.9		)	57.2			67.5			(2.1		)	65.4
Current Derivative Liabilities:
CL&P	Level 3	(64.6		)	—			(64.6		)	(55.1		)	—			(55.1		)	Level 3	(69.2		)	0			(69.2		)	(67.8		)	0			(67.8		)
Other	Level 2	(3.5		)	0.2			(3.3		)	—			—			—			Level 2	0			0			0			(5.2		)	0			(5.2		)
Long-Term Derivative Liabilities:
CL&P	Level 3	(357.7		)	—			(357.7		)	(379.5		)	—			(379.5		)	Level 3	(312.9		)	0			(312.9		)	(338.6		)	0			(338.6		)
Other	Level 2	(0.2		)	—			(0.2		)	—			—			—			Level 2	0			0			0			(0.1		)	0			(0.1		)


⁽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 ~~1E,~~1D, "Summary of Significant Accounting Policies - Fair Value Measurements," to the financial statements.

Derivative Contracts at Fair Value with Offsetting Regulatory Amounts

Commodity Supply and Price Risk Management: As required by regulation, CL&P, along with UI, has capacity-related contracts with generation facilities. CL&P has a sharing agreement with UI, with 80 percent of the costs or benefits of each contract borne by or allocated to CL&P and 20 percent borne by or allocated to UI. The combined capacities of these contracts as of both September 30, ~~2019~~2020 and December 31, ~~2018,~~2019 were ~~679 MW and 787 MW, respectively.~~676 MW. The capacity contracts extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market price received in the ISO-NE capacity markets. In addition, CL&P has a contract to purchase 0.1 million MWh of energy per year through 2020.

As of September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Eversource had New York Mercantile Exchange ~~("NYMEX")~~(NYMEX) financial contracts for natural gas futures in order to reduce variability associated with the price of ~~11.6~~11.4 million and ~~12.5~~9.6 million MMBtu of natural gas, respectively.

For the three months ended September 30, ~~2019~~2020 and ~~2018,~~2019, there were losses of ~~$9.2~~$2.6 million and ~~gains of $1.6~~$9.2 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource's derivative contracts. For the nine months ended September 30, ~~2019~~2020 and ~~2018,~~2019, there were losses of ~~$19.5~~$20.6 million and ~~$25.8~~$19.5 million, respectively.

Fair Value Measurements of Derivative Instruments

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

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

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

The following is a summary of 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, 2019						As of December 31, 2018						As of September 30, 2020								As of December 31, 2019
CL&P	Range					Period Covered	Range					Period Covered	Range				Weighted Average ⁽¹⁾			Period Covered	Range					Period Covered
Capacity Prices	$	3.01	—	7.34	per kW-Month	2023 - 2026	$	4.30	—	7.44	per kW-Month	2022 - 2026	$	4.30	—	$5.12	$	4.57	per kW-Month	2024 - 2026	$	3.01	—	$7.34	per kW-Month	2023 - 2026
Forward Reserve	0.80		—	1.90	per kW-Month	2019 - 2024	0.75		—	1.78	per kW-Month	2019 - 2024
Forward Reserve Prices													0.54		—	0.90	0.72		per kW-Month	2021 - 2024	0.80		—	1.90	per kW-Month	2020 - 2024


⁽¹⁾	Unobservable inputs were weighted by the relative future capacity and forward reserve prices and contractual MWs over the periods covered.

Exit price premiums of ~~2.6~~1 percent through ~~14.1~~12 percent, or a weighted average of 10.9 percent, are also applied to these contracts and reflect the uncertainty and illiquidity premiums that would be required based on the most recent market activity available for similar type contracts. The risk premium was weighted by the relative fair value of the net derivative instruments.

Significant increases or decreases in future capacity or forward reserve prices in isolation would decrease or increase, respectively, the fair value of the derivative liability. Any increases in risk premiums would increase the fair value of the derivative liability. Changes in these fair values are recorded as a regulatory asset or liability and do not impact net income.

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


CL&P	For the Three Months Ended September 30,						For the Nine Months Ended September 30,						For the Three Months Ended September 30,						For the Nine Months Ended September 30,
(Millions of Dollars)	2019			2018			2019			2018			2020			2019			2020			2019
Derivatives, Net:
Fair Value as of Beginning of Period	$	(345.4	)	$	(369.3	)	$	(356.5	)	$	(362.3	)	$	(322.0	)	$	(345.4	)	$	(329.2	)	$	(356.5	)
Net Realized/Unrealized (Losses)/Gains Included in Regulatory Assets	(8.5		)	1.2			(16.4		)	(27.0		)
Net Realized/Unrealized Losses Included in Regulatory Assets													(4.7		)	(8.5		)	(22.3		)	(16.4		)
Settlements	11.6			8.2			30.6			29.4			14.9			11.6			39.7			30.6
Fair Value as of End of Period	$	(342.3	)	$	(359.9	)	$	(342.3	)	$	(359.9	)	$	(311.8	)	$	(342.3	)	$	(311.8	)	$	(342.3	)

5. MARKETABLE SECURITIES

Eversource holds marketable securities that are primarily used to fund certain non-qualified executive benefits. The trusts that hold marketable securities are not subject to regulatory oversight by state or federal agencies. CYAPC and YAEC maintain legally restricted trusts, each of which holds marketable securities, to fund the spent nuclear fuel removal obligations of their nuclear fuel storage facilities.

Equity Securities: Unrealized gains and losses on equity securities held in Eversource's non-qualified executive benefit trust are recorded in Other Income, Net on the statements of income. The fair value of these equity securities as of September 30, ~~2019~~2020 and December 31, ~~2018~~2019 was ~~$43.4~~$36.8 million and ~~$44.0~~$45.7 million, respectively. For ~~each of~~ the three months ended September 30, ~~2019~~2020 and ~~2018,~~2019, there were unrealized gains of $1.6 million and $2.4 million, respectively, recorded in Other Income, Net related to these equity securities. For the nine months ended September 30, ~~2019~~2020 and ~~2018,~~2019, there were unrealized losses of $1.0 million and unrealized gains of $5.7 ~~million and $2.6~~ million, respectively.

Eversource's equity securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of ~~$163.7~~$189.5 million and ~~$200.0~~$182.8 million as of September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively. Unrealized gains and losses for these spent nuclear fuel trusts are subject to regulatory accounting treatment and 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.

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


	As of September 30, 2019									As of December 31, 2018									As of September 30, 2020									As of December 31, 2019
Eversource (Millions of Dollars)	Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value		Amortized Cost		Pre-Tax Unrealized Gains		Pre-Tax Unrealized Losses			Fair Value
Debt Securities	$	203.0	$	8.9	$	(0.1	)	$	211.8	$	190.0	$	0.4	$	(4.0	)	$	186.4	$	216.1	$	11.1	$	(0.2	)	$	227.0	$	228.4	$	5.8	$	(0.1	)	$	234.1

Eversource's debt securities include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts in the amounts of ~~$174.7~~$194.0 million and ~~$143.9~~$198.1 million as of September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively.

Unrealized gains and losses on available-for-sale debt securities held in Eversource's non-qualified benefit trust are recorded in Accumulated Other Comprehensive ~~Income.~~Income, excluding amounts related to credit losses or losses on securities intended to be sold, which are recorded in Other Income, Net. There have been no significant unrealized losses ~~other-than-temporary impairments, or~~and no credit losses for the three and nine months ended September 30, 2020 and 2019, and ~~2018.~~ no allowance for credit losses as of September 30, 2020. 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.~~security, and the severity of the impairment. For ~~asset-backed~~asset-

backed debt securities, underlying collateral and expected future cash flows are also evaluated.

Debt securities included in Eversource's non-qualified benefit trust portfolio are investment-grade bonds with a lower default risk based on their credit quality.

As of September 30, ~~2019,~~2020, the contractual maturities of available-for-sale debt securities were as follows:


Eversource (Millions of Dollars)	Amortized Cost		Fair Value		Amortized Cost		Fair Value
Less than one year⁽¹⁾	$	28.6	$	28.5	$	51.1	$	51.1
One to five years	49.8		51.2		45.2		47.4
Six to ten years	30.0		31.9		43.9		47.0
Greater than ten years	94.6		100.2		75.9		81.5
Total Debt Securities	$	203.0	$	211.8	$	216.1	$	227.0


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

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

Fair Value Measurements: The following table presents the marketable securities recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:


Eversource (Millions of Dollars)	As of September 30, 2019		As of December 31, 2018		As of September 30, 2020		As of December 31, 2019
Level 1:
Mutual Funds and Equities	$	207.1	$	244.0	$	226.3	$	228.5
Money Market Funds	19.6		25.9		45.6		46.0
Total Level 1	$	226.7	$	269.9	$	271.9	$	274.5
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury)	$	95.2	$	79.6	$	64.7	$	96.8
Corporate Debt Securities	49.5		39.5		64.9		44.0
Asset-Backed Debt Securities	13.1		14.0		12.0		12.9
Municipal Bonds	25.6		19.2		30.4		26.7
Other Fixed Income Securities	8.8		8.2		9.4		7.7
Total Level 2	$	192.2	$	160.5	$	181.4	$	188.1
Total Marketable Securities	$	418.9	$	430.4	$	453.3	$	462.6

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

6. SHORT-TERM AND LONG-TERM DEBT

Short-Term Debt - Commercial Paper Programs and Credit Agreements: As of September 30, 2020, Eversource parent ~~has~~had a $1.45 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. On November 2, 2020, Eversource parent’s commercial paper program was increased to $2.00 billion. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas and Aquarion Water Company of Connecticut are ~~also~~ parties to a five-year $1.45 billion revolving credit facility, which terminates on December ~~8, 2023. The~~6, 2024. On October 21, 2020, Eversource parent and Eversource Gas Company of Massachusetts entered into a short-term $550 million revolving credit facility, ~~serves~~which terminates on October 20, 2021. These revolving credit facilities serve to backstop Eversource parent's ~~$1.45~~$2.00 billion commercial paper program.

NSTAR Electric has a $650 million commercial paper program allowing NSTAR Electric to issue commercial paper as a form of short-term debt. NSTAR Electric is also a party to a five-year $650 million revolving credit facility, which terminates on December ~~8, 2023.~~6, 2024. The revolving credit facility serves to backstop NSTAR Electric's $650 million commercial paper program.

The amount of borrowings outstanding and available under the commercial paper programs were as follows:


	Borrowings Outstanding as of				Available Borrowing Capacity as of				Weighted-Average Interest Rate as of					Borrowings Outstanding as of							Available Borrowing Capacity as of						Weighted-Average Interest Rate as of
	September 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018		September 30, 2019			December 31, 2018		September 30, 2020			December 31, 2019				September 30, 2020			December 31, 2019			September 30, 2020			December 31, 2019
(Millions of Dollars)	September 30, 2019				September 30, 2019				September 30, 2019			December 31, 2018		September 30, 2020			December 31, 2019				September 30, 2020			December 31, 2019			September 30, 2020			December 31, 2019
Eversource Parent Commercial Paper Program	$	684.5	December 31, 2018	$	631.5	$	December 31, 2018	765.5			$	818.5			2.25	%	2.77	%	$	0		$	1,224.9		$	1,450.0			$	225.1		0	%	1.98	%
NSTAR Electric Commercial Paper Program	28.0		278.5		622.0		371.5		1.98	%		2.50	%	60.5			10.5				589.5			639.5			0.10	%		1.63	%

There were 0 borrowings outstanding on ~~either~~ the ~~Eversource parent or NSTAR Electric~~ revolving credit facilities as of September 30, ~~2019~~2020 or December 31, ~~2018.~~2019.

On May 15, 2020, CL&P and PSNH entered into uncommitted line of credit agreements, which will expire by May 14, 2021. The CL&P agreements total $450 million and the PSNH agreements total $300 million. There are 0 borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of September 30, 2020.

Amounts outstanding under the commercial paper programs ~~and revolving credit facility~~ are included in Notes Payable and ~~are~~ classified in current liabilities on the Eversource and NSTAR Electric balance sheets, as all borrowings are outstanding for no more than 364 days at one time.

~~We expect~~The Company expects the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with ~~our~~ existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.

Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist ~~them~~ in meeting their short-term borrowing needs. ~~In addition, growth in Eversource's key business initiatives requires cash infusion to those subsidiaries.~~ Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of September 30, 2020, there were intercompany loans from Eversource parent to CL&P of $235.9 million, to PSNH of $29.1 million, and to a subsidiary of NSTAR Electric of $36.6 million. As of December 31, 2019, there were intercompany loans from Eversource parent to CL&P of ~~$173.1~~$63.8 million, to PSNH of ~~$42.1~~$27.0 million, and to ~~Harbor Electric Energy Company ("HEEC"),~~ a ~~wholly-owned~~ subsidiary of NSTAR Electric of ~~$48.7 million. As of December 31, 2018, there were intercompany loans from Eversource parent to PSNH of $57.0~~$30.3 million. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and ~~are~~ classified in current liabilities on the respective subsidiary's balance sheets.

Long-Term Debt Issuance Authorization: On ~~April 26, 2019,~~January 27, 2020, the ~~NHPUC~~DPU approved ~~PSNH’s~~NSTAR Gas' request for authorization to issue up to ~~$300~~$270 million in long-term debt through December 31, ~~2019.~~2021. On ~~August 14, 2019, PURA~~July 31, 2020, the NHPUC approved ~~CL&P's~~PSNH's request for authorization to issue up to ~~$675~~$200 million in long-term debt through December 31, ~~2022.~~2020.

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

(Millions of Dollars) Issue Date Issuance/(Repayment) Maturity Date Use of Proceeds for Issuance/
Repayment Information
CL&P:
4.00% 2018 Series A First Mortgage Bonds ⁽¹⁾
April 2019 $ 300.0
April 2048 Paid short-term borrowings that were used to pay long-term debt that matured on February 1, 2019 and fund capital expenditures and working capital
3.20% 2017 Series A First Mortgage Bonds ⁽²⁾
September 2019 200.0
March 2027 Paid short-term borrowings and fund capital expenditures and working capital
5.50% 2009 Series A First Mortgage Bonds February 2009 (250.0 ) February 2019 Paid at maturity on February 1, 2019
NSTAR Electric:
3.25% 2019 Debentures May 2019 400.0
May 2029 Paid short-term borrowings that were used to fund investments in eligible green expenditures
PSNH:
3.60% 2019 Series T First Mortgage Bonds June 2019 300.0
July 2049 Paid long-term debt due to mature in December 2019, paid short-term borrowings and fund capital expenditures and working capital
Other:
NSTAR Gas 3.74% Series Q First Mortgage Bonds July 2019 75.0
August 2049 Paid short-term borrowings and fund capital expenditures and working capital
Yankee Gas 2.23% Series P First Mortgage Bonds September 2019 100.0
October 2024 Paid long-term debt due to mature in November 2019, paid short-term borrowings and fund capital expenditures and working capital
Yankee Gas 3.30% Series Q First Mortgage Bonds September 2019 100.0
October 2049 Paid long-term debt due to mature in November 2019, paid short-term borrowings and fund capital expenditures and working capital



(Millions of Dollars)	Issuance/(Repayment)			Issue Date or Repayment Date	Maturity Date	Use of Proceeds for Issuance/ Repayment Information
NSTAR Electric:
3.95% 2020 Debentures	$	400.0		March 2020	April 2030	Refinanced investments in eligible green expenditures, which were previously financed in 2018 and 2019
5.10% Series E Senior Notes	(95.0		)	March 2020	March 2020	Paid at maturity
PSNH:
2.40% Series U First Mortgage Bonds	150.0			August 2020	September 2050	Refinanced short-term borrowings, funded capital expenditures and working capital
Other:
Eversource Parent 3.45% Series P Senior Notes	350.0			January 2020	January 2050	Paid short-term borrowings
Eversource Parent 3.45% Series P Senior Notes ⁽¹⁾	300.0			August 2020	January 2050	⁽²⁾
Eversource Parent 0.80% Series Q Senior Notes	300.0			August 2020	August 2025	⁽²⁾
Eversource Parent 1.65% Series R Senior Notes	600.0			August 2020	August 2030	⁽²⁾
NSTAR Gas 4.46% Series N First Mortgage Bonds	(125.0		)	January 2020	January 2020	Paid at maturity
NSTAR Gas 2.33% Series R First Mortgage Bonds	75.0			May 2020	May 2025	Refinanced existing indebtedness, funded capital expenditures and for general corporate purposes
NSTAR Gas 3.15% Series S First Mortgage Bonds	115.0			May 2020	May 2050	Refinanced existing indebtedness, funded capital expenditures and for general corporate purposes
Yankee Gas 4.87% Series K First Mortgage Bonds	(50.0		)	April 2020	April 2020	Paid at maturity
Yankee Gas 2.90% Series R First Mortgage Bonds	70.0			September 2020	September 2050	Refinanced existing indebtedness, funded capital expenditures and for general corporate purposes
Aquarion Water Company of Massachusetts, Inc. and Aquarion Water Capital of Massachusetts, Inc. various term loans and general mortgage bonds	(32.2		)	July 2020	Various	Redeemed long-term debt in conjunction with the sale of assets to the Town of Hingham, Massachusetts


⁽¹⁾	These ~~bonds~~senior notes are part of the same series issued by ~~CL&P~~Eversource parent in ~~March 2018.~~January 2020. The aggregate outstanding principal amount of these ~~bonds~~senior notes is now ~~$800~~$650 million.


⁽²⁾	~~These bonds are part~~The proceeds from these Eversource parent issuances funded a portion of the ~~same series issued by CL&P in March 2017. The aggregate outstanding principal amount of these bonds is now $500 million.~~purchase price for the CMA asset acquisition and refinanced short-term borrowings.

7. RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

Rate Reduction Bonds: On May 8, 2018, PSNH Funding, a wholly-owned subsidiary of PSNH, issued $635.7 million of securitized RRBs in multiple tranches with a weighted average interest rate of 3.66 percent, and final maturity dates ranging from 2026 to 2035. The RRBs are expected to be repaid by February 1, 2033. RRB payments consist of principal and interest and ~~will be~~are paid semi-annually, beginning on February 1, 2019. The RRBs were issued pursuant to a finance order issued by the NHPUC on January 30, 2018 to recover remaining costs resulting from the divestiture of PSNH’s generation assets.

PSNH Funding was formed solely to issue RRBs to finance PSNH's unrecovered remaining costs associated with the divestiture of its generation assets. PSNH Funding is considered a VIE primarily because the equity capitalization is insufficient to support its operations. PSNH has the power to direct the significant activities of the VIE and is most closely associated with the VIE as compared to other interest holders. Therefore, PSNH is considered the primary beneficiary and consolidates PSNH Funding in its consolidated financial statements. The following tables summarize the impact of PSNH Funding on PSNH's balance sheets and income statements:


(Millions of Dollars)
Balance Sheet:	As of September 30, 2019		As of December 31, 2018		As of September 30, 2020		As of December 31, 2019
Restricted Cash - Current Portion (included in Prepayments and Other Current Assets)	$	18.5	$	47.5
Restricted Cash - Current Portion (included in Current Assets)					$	18.8	$	32.5
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2		2.1		3.2
Securitized Stranded Costs (included in Regulatory Assets)	576.1		608.4
Securitized Stranded Cost (included in Regulatory Assets)					532.9		565.3
Other Regulatory Liabilities (included in Regulatory Liabilities)	7.7		5.8		7.2		5.6
Accrued Interest (included in Other Current Liabilities)	3.4		14.4		3.2		8.6
Rate Reduction Bonds - Current Portion	43.2		52.3		43.2		43.2
Rate Reduction Bonds - Long-Term Portion	540.1		583.3		496.9		540.1


(Millions of Dollars)	For the Three Months Ended				For the Nine Months Ended
Income Statement:	September 30, 2019		September 30, 2018		September 30, 2019		September 30, 2018
(Millions of Dollars) Income Statement:									For the Three Months Ended				For the Nine Months Ended
									September 30, 2020		September 30, 2019		September 30, 2020		September 30, 2019
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	$	10.8	$	10.2	$	32.2	$	17.1	$	10.8	$	10.8	$	32.4	$	32.2
Interest Expense on RRB Principal (included in Interest Expense)	5.2		6.0		15.9		8.8		4.9		5.2		14.9		15.9

8. PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION

Eversource provides defined benefit retirement plans ~~("Pension Plans")~~(Pension Plans) that cover eligible employees. In addition to the Pension Plans, Eversource maintains non-qualified defined benefit retirement plans ~~("SERP Plans")~~(SERP Plans), which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees. Eversource also provides defined benefit postretirement plans ~~("PBOP Plans")~~(PBOP Plans) that provide life insurance and a health reimbursement arrangement created for the purpose of reimbursing retirees and dependents for health insurance premiums and certain medical expenses to eligible employees that meet certain age and service eligibility requirements. We contributed $112.5 million and $183.2 million to the Pension Plans for the nine months ended September 30, 2019 and 2018, respectively, and $7.9 million and $5.7 million to the PBOP Plans for the nine months ended September 30, 2019 and 2018, respectively.

The components of net periodic benefit expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets for future recovery, are shown below. The service cost component of net periodic benefit ~~expense,~~expense/(income), less the capitalized portion, is included in Operations and Maintenance expense on the statements of income. The remaining components of net periodic benefit expense/(income), less the deferred portion, are included in Other Income, Net on the statements of income. Pension, SERP and PBOP expense reflected in the statements of cash flows for CL&P, NSTAR Electric and PSNH does not include the intercompany allocations or the corresponding capitalized and deferred portion, as these amounts are cash settled on a short-term basis.



	Pension and SERP												PBOP
	For the Three Months Ended September 30, 2020												For the Three Months Ended September 30, 2020
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	18.7		$	5.4		$	3.8		$	2.0		$	2.4		$	0.4		$	0.5		$	0.2
Interest Cost	44.4			9.3			9.7			4.8			6.1			1.1			1.7			0.7
Expected Return on Plan Assets	(99.2		)	(19.8		)	(25.7		)	(11.1		)	(18.3		)	(2.5		)	(8.5		)	(1.4		)
Actuarial Loss	50.7			9.7			14.0			3.8			2.2			0.3			0.6			0.2
Prior Service Cost/(Credit)	0.2			0			0			0			(5.3		)	0.3			(4.2		)	0.1
Total Net Periodic Benefit Expense/(Income)	$	14.8		$	4.6		$	1.8		$	(0.5	)	$	(12.9	)	$	(0.4	)	$	(9.9	)	$	(0.2	)
Intercompany Allocations	N/A			$	2.4		$	2.3		$	0.8		N/A			$	(0.3	)	$	(0.4	)	$	(0.1	)

Pension and SERP
For the Three Months Ended September 30, 2019 For the Three Months Ended September 30, 2018
(Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH
Service Cost $ 16.2
$ 4.4
$ 3.6
$ 1.5
$ 20.9
$ 5.2
$ 4.3
$ 2.7
Interest Cost 54.8
11.4
12.3
6.0
49.2
10.5
10.9
5.5
Expected Return on Pension Plan Assets (91.6 ) (18.1 ) (24.2 ) (10.1 ) (97.8 ) (19.4 ) (26.6 ) (10.8 )
Actuarial Loss 35.6
6.3
11.8
2.3
35.7
7.1
10.1
3.3
Prior Service Cost 0.3
—
—
—
2.0
0.2
0.1
0.1
Total Net Periodic Benefit Expense/(Income) $ 15.3
$ 4.0
$ 3.5
$ (0.3 ) $ 10.0
$ 3.6
$ (1.2 ) $ 0.8
Intercompany Allocations N/A
$ 2.0
$ 1.9
$ 0.5
N/A
$ 1.5
$ 1.6
$ 0.5

Pension and SERP
For the Nine Months Ended September 30, 2019 For the Nine Months Ended September 30, 2018
(Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH
Service Cost $ 51.6
$ 13.6
$ 11.0
$ 5.6
$ 64.2
$ 16.2
$ 13.1
$ 8.4
Interest Cost 163.8
34.4
36.6
18.2
147.1
31.4
32.6
16.4
Expected Return on Pension Plan Assets (275.4 ) (55.1 ) (72.9 ) (30.6 ) (293.8 ) (59.7 ) (78.3 ) (32.6 )
Actuarial Loss 107.9
20.6
33.1
8.2
107.6
21.9
31.0
9.8
Prior Service Cost 0.9
—
0.2
—
6.0
0.8
0.2
0.2
Total Net Periodic Benefit Expense/(Income) $ 48.8
$ 13.5
$ 8.0
$ 1.4
$ 31.1
$ 10.6
$ (1.4 ) $ 2.2
Intercompany Allocations N/A
$ 6.5
$ 6.1
$ 1.8
N/A
$ 4.5
$ 4.8
$ 1.4


	PBOP																								Pension and SERP												PBOP
	For the Three Months Ended September 30, 2019												For the Three Months Ended September 30, 2018												For the Nine Months Ended September 30, 2020												For the Nine Months Ended September 30, 2020
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	2.0		$	0.3		$	0.4		$	0.2		$	2.5		$	0.4		$	0.5		$	0.3		$	57.0		$	16.5		$	11.4		$	6.2		$	7.3		$	1.3		$	1.6		$	0.6
Interest Cost	8.1			1.6			2.4			0.8			7.7			1.5			2.2			0.9			133.0			28.1			29.0			14.5			18.3			3.3			5.0			2.1
Expected Return on Plan Assets	(16.7		)	(2.2		)	(7.5		)	(1.3		)	(18.2		)	(2.6		)	(8.1		)	(1.5		)	(298.8		)	(59.6		)	(77.2		)	(33.5		)	(55.1		)	(7.4		)	(25.5		)	(4.2		)
Actuarial Loss	2.1			0.3			0.8			0.1			2.6			0.4			0.5			0.2			150.7			29.4			41.3			11.8			6.3			0.9			1.8			0.6
Prior Service Cost/(Credit)	(5.8		)	0.2			(4.2		)	0.1			(6.0		)	0.3			(4.3		)	0.1			0.8			0			0.2			0			(15.9		)	0.8			(12.7		)	0.3
Total Net Periodic Benefit Expense/(Income)	$	(10.3	)	$	0.2		$	(8.1	)	$	(0.1	)	$	(11.4	)	$	—		$	(9.2	)	$	—		$	42.7		$	14.4		$	4.7		$	(1.0	)	$	(39.1	)	$	(1.1	)	$	(29.8	)	$	(0.6	)
Intercompany Allocations	N/A			$	(0.2	)	$	(0.3	)	$	(0.1	)	N/A			$	(0.3	)	$	(0.3	)	$	(0.1	)	N/A			$	6.7		$	6.5		$	2.2		N/A			$	(0.9	)	$	(1.0	)	$	(0.4	)

	PBOP
	For the Nine Months Ended September 30, 2019												For the Nine Months Ended September 30, 2018
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	5.9		$	1.1		$	1.3		$	0.5		$	7.5		$	1.4		$	1.6		$	0.9
Interest Cost	24.5			4.7			7.1			2.5			23.0			4.4			6.5			2.5
Expected Return on Plan Assets	(50.1		)	(6.9		)	(22.6		)	(4.0		)	(54.2		)	(7.8		)	(24.4		)	(4.5		)
Actuarial Loss	6.2			1.0			2.5			0.3			7.7			1.2			1.7			0.6
Prior Service Cost/(Credit)	(17.6		)	0.8			(12.7		)	0.3			(17.6		)	0.8			(12.7		)	0.4
Total Net Periodic Benefit Expense/(Income)	$	(31.1	)	$	0.7		$	(24.4	)	$	(0.4	)	$	(33.6	)	$	—		$	(27.3	)	$	(0.1	)
Intercompany Allocations	N/A			$	(0.6	)	$	(0.9	)	$	(0.3	)	N/A			$	(0.8	)	$	(1.0	)	$	(0.3	)



	Pension and SERP												PBOP
	For the Three Months Ended September 30, 2019												For the Three Months Ended September 30, 2019
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	16.2		$	4.4		$	3.6		$	1.5		$	2.0		$	0.3		$	0.4		$	0.2
Interest Cost	54.8			11.4			12.3			6.0			8.1			1.6			2.4			0.8
Expected Return on Plan Assets	(91.6		)	(18.1		)	(24.2		)	(10.1		)	(16.7		)	(2.2		)	(7.5		)	(1.3		)
Actuarial Loss	35.6			6.3			11.8			2.3			2.1			0.3			0.8			0.1
Prior Service Cost/(Credit)	0.3			0			0			0			(5.8		)	0.2			(4.2		)	0.1
Total Net Periodic Benefit Expense/(Income)	$	15.3		$	4.0		$	3.5		$	(0.3	)	$	(10.3	)	$	0.2		$	(8.1	)	$	(0.1	)
Intercompany Allocations	N/A			$	2.0		$	1.9		$	0.5		N/A			$	(0.2	)	$	(0.3	)	$	(0.1	)



	Pension and SERP												PBOP
	For the Nine Months Ended September 30, 2019												For the Nine Months Ended September 30, 2019
(Millions of Dollars)	Eversource			CL&P			NSTAR Electric			PSNH			Eversource			CL&P			NSTAR Electric			PSNH
Service Cost	$	51.6		$	13.6		$	11.0		$	5.6		$	5.9		$	1.1		$	1.3		$	0.5
Interest Cost	163.8			34.4			36.6			18.2			24.5			4.7			7.1			2.5
Expected Return on Plan Assets	(275.4		)	(55.1		)	(72.9		)	(30.6		)	(50.1		)	(6.9		)	(22.6		)	(4.0		)
Actuarial Loss	107.9			20.6			33.1			8.2			6.2			1.0			2.5			0.3
Prior Service Cost/(Credit)	0.9			0			0.2			0			(17.6		)	0.8			(12.7		)	0.3
Total Net Periodic Benefit Expense/(Income)	$	48.8		$	13.5		$	8.0		$	1.4		$	(31.1	)	$	0.7		$	(24.4	)	$	(0.4	)
Intercompany Allocations	N/A			$	6.5		$	6.1		$	1.8		N/A			$	(0.6	)	$	(0.9	)	$	(0.3	)

9. COMMITMENTS AND CONTINGENCIES

A. Environmental Matters

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

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


	As of September 30, 2019			As of December 31, 2018			As of September 30, 2020			As of December 31, 2019
	Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)
Eversource	58	$	70.3	60	$	64.7	55	$	78.8	57	$	81.0
CL&P	15	6.0		15	5.4		15	11.6		15	11.4
NSTAR Electric	15	9.5		16	10.9		13	4.6		15	8.0
PSNH	9	5.7		9	5.4		9	7.2		9	7.5

Included in the number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured gas from coal and other processes, which resulted in certain by-products remaining in the environment that may pose a potential risk to human health and the environment, for which Eversource may have potential liability. The reserve balances related to these former MGP sites were ~~$56.4~~$69.5 million and ~~$50.1~~$67.9 million as of September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively, and related primarily to the natural gas business segment.

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

B. Long-Term Contractual Arrangements

~~On December 28, 2018, under Public Act 17-3, "An Act Concerning Zero Carbon Procurement," DEEP selected~~The following is an update to the ~~Millstone Nuclear Power Station generation facility and Seabrook Nuclear Power Plant, along with smaller generation facilities,~~current status of long-term contractual arrangements set forth in DEEP’s zero-carbon request for proposal. CL&P and UI were directed by DEEP to enter into ten-year contracts to purchase a combined total of approximately 9 million MWh annually from the Millstone generation facility. On March 15, 2019, CL&P and UI each signed a ten-year contract with the owner of Millstone Nuclear Power Station in order to purchase a combined amount of approximately 50 percentNote 13B of the ~~facility's output (approximately 40 percent by CL&P). The Millstone Nuclear Power Station has a 2,112 MW nameplate capacity. PURA approved the contracts on September 18, 2019.~~Eversource 2019 Form 10-K.

~~The significant output~~Renewable Energy: Renewable energy contracts include non-cancelable commitments under contracts of NSTAR Electric for the ~~Millstone generation facility, the contract period,~~purchase of energy and ~~the pricing will result in estimated annual contractual commitments of approximately $360 million over the ten-year contract term. CL&P plans to sell the~~RECs from renewable energy purchased under this contract into the market and use the proceeds from these energy sales to offset the contract costs. As the net costs under this contract will be recovered from customers in future rates, the contract will not have an impact on the net income of CL&P. Energy deliveries under this contract began in October 2019, for which payments will begin in November 2019. Contracts with other suppliers selected by DEEP are being reviewed by PURA.facilities.



NSTAR Electric	October - December 2020
(Millions of Dollars)	October - December 2020		2021		2022		2023		2024		Thereafter		Total
Renewable Energy	$	24.3	$	98.5	$	100.0	$	75.4	$	72.9	$	594.5	$	965.6

C. Guarantees and Indemnifications

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

Eversource parent issued a guaranty on behalf of its subsidiary, NPT, under which, beginning at the time the Northern Pass Transmission line would go into commercial operation, Eversource parent would guarantee the financial obligations of NPT under the TSA with HQ in an amount not to exceed $25 million. Eversource parent's obligations under the guaranty expire upon the full, final and indefeasible payment of the guaranteed obligations. In the second quarter of 2019, Eversource concluded that construction of the NPT project was no longer probable. For further information regarding the impairment of NPT, see Note 1C, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements. While this guaranty is currently outstanding, it is expected to be extinguished in connection with the final dissolution of NPT.

Management does not anticipate a material impact to net income or cash flows as a result of these various guarantees and indemnifications. The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries and affiliates to external parties as of September 30, ~~2019:~~2020:


Company	Description	Maximum Exposure (in millions)		Expiration Dates	Description	Maximum Exposure (in millions)		Expiration Dates
On behalf of subsidiaries:
Various	Surety Bonds⁽¹⁾	$	34.3	2019 - 2021	Surety Bonds⁽¹⁾	$	30.9	2020 - 2023
Rocky River Realty Company and Eversource Service	Lease Payments for Real Estate	6.8		2024	Lease Payments for Real Estate	5.6		2024
Bay State Wind	Real Estate Purchase	2.5		2020
Bay State Wind LLC					Real Estate Purchase	2.5		2021
Sunrise Wind LLC					OREC Capacity Production ⁽²⁾	2.2		-


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

⁽²⁾

On October 25, 2019, Eversource parent issued a guaranty on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guaranty Sunrise Wind LLC’s performance of certain obligations, in an amount not to exceed $15.4 million, under the Offshore Wind Renewable Energy Certificate Purchase and Sale Agreement (the Agreement). The Agreement was executed on October 23, 2019, by and between the New York State Energy Research and Development Authority (NYSERDA) and Sunrise Wind LLC. The Company regularly reviews performance risk under this arrangement, and in the event it becomes probable that Eversource parent will be required to perform under the guarantee, the amount of probable payment will be recorded. As of September 30, 2020, the fair value of the guarantee was immaterial.

On September 16, 2020, Eversource parent entered into a guaranty on behalf of ~~its 50 percent-owned joint venture subsidiary, Sunrise Wind~~Eversource Investment LLC, ~~whereby~~which holds Eversource's investments in wind-related equity method investments, under which Eversource parent ~~will guaranty Sunrise Wind LLC’s performance~~would guarantee Eversource Investment LLC's obligations under a letter of ~~certain obligations,~~credit facility with a financial institution that Eversource Investment LLC may request in an aggregate amount ~~not~~of up to exceed $15.4 million, under the Offshore Wind Renewable Energy Certificate Purchase and Sale Agreement (the "Agreement"). The Agreement was executed on October 23, 2019, by and between the New York State Energy Research and Development Authority ("NYSERDA") and Sunrise Wind LLC. Obligations of Eversource parent under the guaranty expire at such time as the guaranteed obligations have been fully performed.approximately $25 million.

D. Spent Nuclear Fuel Obligations - Yankee Companies

CL&P, NSTAR Electric and PSNH have plant closure and fuel storage cost obligations to the Yankee Companies, which have each completed the physical decommissioning of their respective nuclear power facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies fund these costs through litigation proceeds received from the DOE and, to the extent necessary, through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. CL&P, NSTAR Electric and PSNH, in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies collect amounts that management believes are adequate to recover the remaining plant closure and fuel storage cost estimates for the respective plants. Management believes CL&P and NSTAR Electric will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers.

Spent Nuclear Fuel Litigation:

The Yankee Companies have filed complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to accept delivery of, and provide for a permanent facility to store, spent nuclear fuel pursuant to the terms of the 1983 spent fuel and ~~high level~~high-level waste disposal contracts between the Yankee Companies and the DOE. The court ~~had~~ previously awarded the Yankee Companies damages for ~~Phase~~Phases I, II and III of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2012, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.

DOE Phase IV Damages - On May 22, 2017, each of the Yankee Companies filed ~~subsequent~~a fourth set of lawsuits against the DOE in the Court of Federal

Claims. The Yankee Companies sought monetary damages totaling $104.4 million for CYAPC, YAEC and MYAPC, resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2013 to 2016 ~~(“DOE~~(DOE Phase ~~IV”)~~IV). On February 21, 2019, the Yankee Companies received a partial summary judgment and partial final judgment in their favor for the undisputed amount of monetary damages of $103.2 million. The court awarded CYAPC, YAEC and MYAPC damages of $40.7 million, $28.1 million and $34.4 million, respectively. The DOE did not appeal the court's judgment and the decision became final on April 23, 2019. On June 12, 2019, ~~CYAPC and YAEC~~each of the Yankee Companies received the damages ~~of $40.7 million and $28.1 million, respectively, which were recorded as restricted cash within Other Long-Term Assets on the Eversource consolidated balance sheet as of September 30, 2019.~~

proceeds. On June 12, 2019, the court accepted an offer of judgment in the amount of $0.5 million to settle the disputed amount of approximately $1 million in Phase IV contested damages. The Yankee Companies received the $0.5 million payment in July 2019.

In September 2019, the Yankee Companies made a required informational filing with FERC as to the use of ~~proceeds. FERC~~proceeds, for which approval was received in the fourth quarter of 2019. In December 2019, YAEC and ~~payment~~MYAPC returned proceeds of $5.4 million and $21.0 million, respectively, to its member companies, of which the Eversource utilities (CL&P, NSTAR Electric and PSNH) ~~is expected in the fourth quarter~~received a total of ~~2019. At this time, the damages are primarily expected to be used by the Yankee Companies to fund remaining fuel storage obligations,~~$2.8 million from YAEC and ~~management does not expect significant amounts to be refunded to the utilities.~~$5.0 million from MYAPC. The Eversource utilities ~~will ultimately~~ refund ~~any~~these amounts received to their utility customers. Also, in December 2019, CYAPC paid $29.0 million to the DOE to partially settle its pre-1983 spent nuclear fuel obligation.

E. FERC ROE Complaints

Four separate complaints ~~have been~~were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively, the ~~"Complainants")~~Complainants). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive ~~("incentive cap")~~(incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, the FERC set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the ~~"Court")~~Court).

All amounts associated with the first complaint period have been refunded, which totaled $38.9 million (pre-tax and excluding interest) at Eversource and reflected both the base ROE and incentive cap prescribed by the FERC order. The refund consisted of $22.4 million for CL&P, $13.7 million for NSTAR Electric and $2.8 million for PSNH.

Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of September 30, 2020 and December 31, 2019. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of September 30, 2020 and December 31, 2019.

On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. ~~The parties to these proceedings were directed to submit briefs on this new proposed framework and how they would apply the proposed framework in each of the four complaint proceedings.~~ Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.

The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those ~~preliminary~~illustrative calculations indicated that for the first complaint period, for the NETOs, ~~that~~which FERC concludes are of average financial risk, ~~(1) a preliminary range of presumptively just and reasonable base ROEs is 9.60 percent to 10.99 percent; (2) the pre-existing base ROE of 11.14 percent is therefore unjust and unreasonable; (3)~~ the preliminary just and reasonable base ROE is 10.41 ~~percent;~~percent and ~~(4)~~ the preliminary incentive cap on total ROE is 13.08 percent.

If the results of ~~these~~the illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods.

~~Although the order provided illustrative calculations, FERC stated that these calculations are merely preliminary. The FERC’s~~ These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC ~~order, as changes~~order.

On November 21, 2019, FERC issued Opinion No. 569 affecting the two pending transmission ROE complaints against the Midcontinent ISO (MISO) transmission owners, in which FERC adopted a new methodology for determining base ROEs. Various parties sought rehearing. On December 23, 2019, the NETOs filed supplementary materials in the NETOs' four pending cases to respond to this new methodology because of the uncertainty of the applicability to the NETOs’ cases.

On May 21, 2020, the FERC issued its order in Opinion No. 569-A on the rehearing of the MISO transmission owners' cases, in which FERC again changed its methodology for determining the MISO transmission owners' base ROEs. Various parties have appealed the MISO transmission owners' opinion. This new methodology differs significantly from the methodology proposed by FERC ~~are possible as a result of the parties’ arguments and calculations~~ in the briefing process. Until FERC issues a final decision on each of these four complaints, there is significant uncertainty, and at this time, the Company cannot reasonably estimate a range of gain or loss for any of the four complaint proceedings. Theits October 16, 2018 order to determine the NETOs' base ROEs in its four pending cases.

Given the significant uncertainty regarding the applicability of the FERC ~~order or~~opinions in the ~~2019 briefs did not provide a~~MISO transmission owners' two complaint cases to the NETOs' pending four complaint cases, Eversource concluded that there is no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint ~~periods.~~periods at this time. As well, Eversource cannot reasonably estimate a range of any gain or loss for any of the four complaint proceedings at this time.

Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.

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

F. Eversource and NSTAR Electric Boston Harbor Civil Action

~~On July 15,~~In 2016, the United States Attorney on behalf of the United States Army Corps of Engineers filed a civil action in the United States District Court for the District of Massachusetts ~~under provisions of the Rivers and Harbors Act of 1899 and the Clean Water Act~~ against NSTAR Electric, HEEC, and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the "Defendants"). The action alleged that the Defendants failed to comply with certain permitting requirements related to the placement of the HEEC-owned electric distribution cable beneath Boston Harbor. The action sought an order to compel HEEC to comply with cable depth requirements in the United States Army Corps of Engineers' permit or alternatively to remove the electric distribution cable and cease unauthorized work in U.S. waterways. The action also sought civil penalties and other costs.

The parties reached a settlement pursuant to which HEEC agreed to install a new 115kV distribution cable across Boston Harbor to Deer Island, utilizing a different route, and remove portions of the existing cable. Upon installation and completion of the new cable and removal of the portions of the existing cable, all issues surrounding the current permit from the United States Army Corps of Engineers are expected to be resolved, and such litigation is expected to be dismissed with prejudice. Construction of the new distribution cable was completed in August 2019 and removal of the portions of the existing cable iswas completed in January 2020. All issues surrounding the current permit from the United States Army Corps of Engineers are expected to be ~~completed by May of 2020.~~

NSTAR Electric agreed to provide a rate base credit of $17.5 million to the Massachusetts Water Resources Authority for the new cable. This negotiated credit resulted in the initial $17.5 million of construction costs on the new cable being expensed as incurred, all of which was fully expensed in 2018. In connectionresolved, and subsequently, such litigation then dismissed with the new cable that was placed into service, a corresponding ARO was recognized for approximately $32 million within Other Long-Term Liabilities on the Eversource and NSTAR Electric balance sheets as of September 30, 2019.prejudice.

10. ~~LEASES~~

Eversource, including CL&P, NSTAR Electric and PSNH, has entered into lease agreements as a lessee for the use of land, office space, service centers, vehicles, information technology, and equipment. These lease agreements are classified as either finance or operating leases and the liability and right-of-use asset are recognized on the balance sheet at lease commencement. Leases with an initial term of 12 months or less are not recorded on the balance sheet and are recognized as lease expense on a straight-line basis over the lease term.

Eversource determines whether or not a contract contains a lease based on whether or not it provides Eversource with the use of a specifically identified asset for a period of time, as well as both the right to direct the use of that asset and receive the significant economic benefits of the asset. Eversource has elected the practical expedient to not separate non-lease components from lease components and instead to account for both as a single lease component, with the exception of the information technology asset class where the lease and non-lease components are separated.

The provisions of Eversource, CL&P, NSTAR Electric and PSNH lease agreements contain renewal options. The renewal options range from one year to twenty years. The renewal period is included in the measurement of the lease liability if it is reasonably certain that Eversource will exercise these renewal options.

For leases entered into or modified after the January 1, 2019 implementation date, the discount rate utilized for classification and measurement purposes as of the inception date of the lease is based on each company's collateralized incremental interest rate to borrow over a comparable term for an individual lease, as the rate implicit in the lease is not determinable.

CL&P and PSNH entered into certain contracts for the purchase of energy that qualify as leases. These contracts do not have minimum lease payments and therefore are not recognized as a lease liability on the balance sheet and are not reflected in the future minimum lease payments table below. Expense related to these contracts are included as variable lease cost in the table below. The expense and long-term obligation for these contracts are included in the annually reported contractual obligations table in Note 12B, "Commitments and Contingencies - Long-Term Contractual Arrangements," of the Eversource 2018 Form 10-K.

~~The components of lease cost, prior to amounts capitalized, are as follows:~~

For the Three Months Ended September 30, 2019 For the Nine Months Ended September 30, 2019
(Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH
Financing Lease Cost:
Amortization of Right-of-use-Assets $ 0.4
$ 0.2
$ 0.1
$ —
$ 1.1
$ 0.6
$ 0.1
$ 0.1
Interest on Lease Liabilities 0.3
0.1
0.1
—
1.0
0.4
0.4
—
Total Finance Lease Cost 0.7
0.3
0.2
—
2.1
1.0
0.5
0.1
Operating Lease Cost 2.9
0.1
0.5
—
8.9
0.3
1.3
0.1
Variable Lease Cost 15.3
3.6
—
11.7
46.4
10.1
—
36.3
Total Lease Cost $ 18.9
$ 4.0
$ 0.7
$ 11.7
$ 57.4
$ 11.4
$ 1.8
$ 36.5

Operating lease cost, less the capitalized portion, is included in Operations and Maintenance (or Purchased Power, Fuel and Transmission expense for transmission segment leases) on the statements of income. Amortization of finance lease assets is included in Depreciation on the statements of income. Interest expense on finance leases is included in Interest Expense, Net on the statements of income.

~~Supplemental balance sheet information related to leases is as follows:~~

As of September 30, 2019
(Millions of Dollars) Balance Sheet Classification Eversource CL&P NSTAR Electric PSNH
Operating Leases:
Operating Lease Right-of-use-Assets, Net Other Long-Term Assets $ 52.3
$ 0.9
$ 24.2
$ 0.4
Operating Lease Liabilities
Operating Lease Liabilities - Current Portion Other Current Liabilities $ 8.9
$ 0.5
$ 0.6
$ —
Operating Lease Liabilities - Long-Term Other Long-Term Liabilities 43.4
0.4
23.6
0.4
Total Operating Lease Liabilities $ 52.3
$ 0.9
$ 24.2
$ 0.4
Finance Leases:
Finance Lease Right-of-use-Assets, Net Property, Plant and Equipment, Net $ 8.8
$ 2.2
$ 3.4
$ 0.9
Finance Lease Liabilities
Finance Lease Liabilities - Current Portion Other Current Liabilities $ 2.3
$ 1.6
$ —
$ 0.1
Finance Lease Liabilities - Long-Term Other Long-Term Liabilities 8.7
1.8
4.4
0.8
Total Finance Lease Liabilities $ 11.0
$ 3.4
$ 4.4
$ 0.9

The finance lease payments that NSTAR Electric will make over the next twelve months are entirely interest-related, due to escalating payments. As such, none of the finance lease payments over the next twelve months will reduce the finance lease liability.

~~Other information related to leases is as follows (in millions of dollars, unless otherwise noted):~~

Eversource CL&P NSTAR Electric PSNH
As of September 30, 2019
Weighted-Average Remaining Lease Term (Years):
Operating Leases 12
2
20
9
Financing Leases 11
2
22
9
Weighted-Average Discount Rate (Percentage):
Operating Leases 3.9 % 2.5 % 4.1 % 3.7 %
Financing Leases 4.2 % 10.5 % 2.9 % 3.5 %

For the Three Months Ended September 30, 2019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases $ 2.9
$ 0.1
$ 0.5
$ —
Operating Cash Flows from Finance Leases 0.3
0.1
0.1
—
Financing Cash Flows from Finance Leases 0.5
0.4
—
—
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities 0.9
0.8
—
—
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities —
—
—
—

For the Nine Months Ended September 30, 2019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases $ 8.7
$ 0.3
$ 1.2
$ 0.1
Operating Cash Flows from Finance Leases 1.0
0.4
0.4
—
Financing Cash Flows from Finance Leases 1.5
1.0
—
0.1
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities 2.6
1.0
—
0.2
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities 1.3
—
—
—

~~Future minimum lease payments, excluding variable costs, under long-term leases, as of September 30, 2019 are as follows:~~

Operating Leases Finance Leases

(Millions of Dollars)
Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH
October 1, 2019 through December 31, 2019 $ 2.6
$ 0.1
$ 0.3
$ —
$ 0.9
$ 0.5
$ 0.1
$ —
Year Ending December 31,
2020 10.1
0.5
1.6
0.1
3.4
2.0
0.5
0.1
2021 8.9
0.2
1.6
0.1
2.9
1.5
0.5
0.1
2022 7.4
—
1.6
0.1
1.5
—
0.6
0.1
2023 4.9
—
1.6
—
0.7
—
0.6
0.1
2024 2.8
—
1.6
—
0.7
—
0.6
0.1
Thereafter 28.9
0.1
28.7
0.2
13.3
—
12.8
0.5
Future lease payments 65.6
0.9
37.0
0.5
23.4
4.0
15.7
1.0
Less amount representing interest 13.3
—
12.8
0.1
12.4
0.6
11.3
0.1
Present value of future minimum lease payments $ 52.3
$ 0.9
$ 24.2
$ 0.4
$ 11.0
$ 3.4
$ 4.4
$ 0.9

~~At December 31, 2018, future minimum rental payments, excluding executory costs, such as property taxes, state use taxes, insurance, and maintenance were as follows:~~

Operating Leases
(Millions of Dollars)
Eversource CL&P NSTAR Electric PSNH
2019 $ 11.5
$ 1.5
$ 7.2
$ 0.5
2020 9.8
1.4
6.0
0.4
2021 8.7
1.2
5.3
0.4
2022 7.2
1.1
4.4
0.4
2023 4.7
0.5
3.1
0.2
Thereafter 32.7
0.2
29.5
0.3
Future minimum lease payments $ 74.6
$ 5.9
$ 55.5
$ 2.2

Capital Leases
(Millions of Dollars)
Eversource CL&P NSTAR Electric PSNH
2019 $ 3.4
$ 2.0
$ 0.5
$ 0.1
2020 3.4
2.0
0.5
0.1
2021 2.9
1.5
0.5
0.1
2022 1.5
—
0.6
0.1
2023 0.7
—
0.6
0.1
Thereafter 13.9
—
13.4
0.5
Future minimum lease payments 25.8
5.5
16.1
1.0
Less amount representing interest 13.8
1.0
12.4
0.1
Present value of future minimum lease payments $ 12.0
$ 4.5
$ 3.7
$ 0.9

~~11.~~ 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, Long-Term Debt and Rate Reduction Bonds: 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 and RRB 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 table below are classified as Level 2 within the fair value hierarchy. Carrying amounts and estimated fair values are as follows:


	Eversource				CL&P				NSTAR Electric				PSNH				Eversource				CL&P				NSTAR Electric				PSNH
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
As of September 30, 2019:
As of September 30, 2020:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	160.3	$	116.2	$	116.6	$	43.0	$	43.7	$	—	$	—	$	155.6	$	166.6	$	116.2	$	122.0	$	43.0	$	44.6	$	0	$	0
Long-Term Debt	14,293.2		15,479.2		3,518.5		4,104.4		3,341.6		3,695.3		1,101.5		1,165.7		15,814.5		17,943.7		3,518.1		4,336.7		3,642.8		4,285.4		1,099.0		1,192.1
Rate Reduction Bonds	583.3		634.1		—		—		—		—		583.3		634.1		540.1		603.0		0		0		0		0		540.1		603.0

As of December 31, 2018:
As of December 31, 2019:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	156.8	$	116.2	$	113.8	$	43.0	$	43.0	$	—	$	—	$	155.6	$	162.0	$	116.2	$	117.8	$	43.0	$	44.2	$	0	$	0
Long-Term Debt	13,086.1		13,154.9		3,254.0		3,429.2		2,944.8		3,024.1		805.2		819.5		14,098.2		15,170.2		3,518.1		4,058.0		3,342.1		3,659.9		951.6		1,005.7
Rate Reduction Bonds	635.7		645.8		—		—		—		—		635.7		645.8		583.3		625.9		0		0		0		0		583.3		625.9

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

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

~~12.~~

11. ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

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


	For the Nine Months Ended September 30, 2019												For the Nine Months Ended September 30, 2018												For the Nine Months Ended September 30, 2020											For the Nine Months Ended September 30, 2019
Eversource (Millions of Dollars)	Qualified Cash Flow Hedging Instruments			Unrealized Gains/(Losses) on Marketable Securities			Defined Benefit Plans			Total			Qualified Cash Flow Hedging Instruments			Unrealized Losses on Marketable Securities			Defined Benefit Plans			Total			Qualified Cash Flow Hedging Instruments			Unrealized Gains on Marketable Securities		Defined Benefit Plans			Total			Qualified Cash Flow Hedging Instruments			Unrealized Gains/(Losses) on Marketable Securities			Defined Benefit Plans			Total
Balance as of January 1st	$	(4.4	)	$	(0.5	)	$	(55.1	)	$	(60.0	)	$	(6.2	)	$	—		$	(60.2	)	$	(66.4	)	$	(3.0	)	$	0.7	$	(62.8	)	$	(65.1	)	$	(4.4	)	$	(0.5	)	$	(55.1	)	$	(60.0	)

OCI Before Reclassifications	—			1.3			2.6			3.9			—			(0.7		)	2.6			1.9			0			0.3		(1.6		)	(1.3		)	0			1.3			2.6			3.9
Amounts Reclassified from AOCI	0.9			—			3.2			4.1			1.6			—			3.3			4.9			1.2			0		4.8			6.0			0.9			0			3.2			4.1
Net OCI	0.9			1.3			5.8			8.0			1.6			(0.7		)	5.9			6.8			1.2			0.3		3.2			4.7			0.9			1.3			5.8			8.0
Balance as of September 30th	$	(3.5	)	$	0.8		$	(49.3	)	$	(52.0	)	$	(4.6	)	$	(0.7	)	$	(54.3	)	$	(59.6	)	$	(1.8	)	$	1.0	$	(59.6	)	$	(60.4	)	$	(3.5	)	$	0.8		$	(49.3	)	$	(52.0	)

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

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses that arose during the year and were recognized in AOCI. The unamortized actuarial gains and losses and prior service costs on the defined benefit plans are amortized from AOCI into Other Income, Net over the average future employee service period, and are reflected in amounts reclassified from AOCI.

~~Eversource did not elect to reclassify the income tax effects of the Tax Cuts and Jobs Act from AOCI to Retained Earnings as permitted by ASU 2018-02,~~ ~~Income Statement—Reporting Comprehensive Income (Topic 220)~~.

~~13.~~12. COMMON SHARES

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


	Shares										Shares
			Authorized as of September 30, 2019 and December 31, 2018			Issued as of								Authorized as of September 30, 2020 and December 31, 2019			Issued as of
	Par Value				September 30, 2019			December 31, 2018		Par Value				Authorized as of September 30, 2020 and December 31, 2019		September 30, 2020			December 31, 2019
Eversource	$	5	Authorized as of September 30, 2019 and December 31, 2018	380,000,000			339,858,402			333,878,402		$	5		380,000,000			357,818,402			345,858,402
CL&P	$	10	24,500,000			6,035,205			6,035,205		$	10		24,500,000			6,035,205			6,035,205
NSTAR Electric	$	1	100,000,000			200			200		$	1		100,000,000			200			200
PSNH	$	1	100,000,000			301			301		$	1		100,000,000			301			301

Common Share ~~Issuance~~Issuances and 2019 Forward Sale Agreement:On June 4,15, 2020, Eversource completed an equity offering of 6,000,000 common shares at a price per share of $86.26. Eversource used the net proceeds of this offering to fund a portion of the purchase of the assets of CMA that closed on October 9, 2020. The issuance of these common shares resulted in proceeds of $509.2 million, net of issuance costs.

In June 2019, Eversource completed an equity offering ~~of 17,940,000 common shares,~~ consisting of 5,980,000 common shares issued directly by the Company and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resulted in proceeds of $426.9 million, net of issuance costs, and was reflected in shareholders’ equity and as a financing activity on the statement of cash flows.

Under the forward sale agreement, ~~a total of~~ 11,960,000 common shares were borrowed from third parties and sold by the underwriters. The forward sale agreement ~~allows~~allowed Eversource, at its election and prior to May 29, 2020, to physically settle the forward sale agreement by issuing common shares in exchange for net proceeds at the then-applicable forward sale price specified by the agreement (initially, $71.48 per share) or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt of shares or cash. The forward sale price iswas subject to adjustment daily based on a floating interest rate factor and ~~will~~would decrease in respect of certain fixed amounts specified in the agreement, such as dividends.

~~Eversource’s intent is to~~Eversource issued 6,000,000 common shares under the forward sale agreement in December 2019. On March 23, 2020, Eversource physically ~~settle~~settled a portion of the forward sale agreement by ~~issuing~~delivering 1,500,000 common ~~shares. As~~shares in exchange for net proceeds of ~~September 30, 2019, if~~$105.7 million. Subsequently, on March 26, 2020, Eversource ~~had elected to net settle~~physically settled the remaining portion of the forward sale agreement ~~Eversource would have been required to pay $169.7 million under a cash settlement or would have been required to deliver 1,985,105~~by delivering 4,460,000 common shares ~~under a~~in exchange for net proceeds of $314.1 million. The forward sale price used to determine the cash proceeds received by Eversource was calculated based on the initial forward sale price, as adjusted in accordance with the forward sale agreement.

The March and June 2020 common share ~~settlement.~~issuances of 5,960,000 and 6,000,000, respectively, resulted in total proceeds of $929.0 million, net of issuance costs, and were reflected in shareholders' equity and as financing activities on the statement of cash flows.

Issuances of shares under the forward sale agreement are classified as equity transactions. Accordingly, no amounts relating to the forward sale agreement ~~have or will be~~were recorded in the financial statements until settlements ~~take~~took place. Prior to any settlements, the only impact to the financial statements iswas the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method. See Note ~~15,~~14, "Earnings Per Share," to the financial statements for information on the forward sale agreement’s impact on the calculation of diluted EPS.

Eversource used the net proceeds received from the direct issuance of common shares and the net proceeds received from settlement of the forward sale agreement to repay short-term debt under the commercial paper program, to partially fund the purchase of the assets of CMA, to fund capital spending and clean energy initiatives, and for general corporate purposes.

Treasury Shares: As of September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, there were ~~16,124,979~~15,020,929 and ~~16,992,594~~15,977,757 Eversource common shares held as treasury shares, respectively. As of September 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Eversource common shares outstanding were ~~323,733,423~~342,797,473 and ~~316,885,808,~~329,880,645, respectively.

~~Beginning in 2019,~~ Eversource ~~began issuing~~issues treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan. The issuance of treasury shares represents a non-cash transaction, as the treasury shares were used to fulfill Eversource's obligations that require the issuance of common shares.

~~14.~~13. COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

Dividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for each of the three months ended September 30, ~~2019~~2020 and ~~2018~~2019 and $5.6 million for each of the nine months ended September 30, ~~2019~~2020 and ~~2018.~~2019. These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of September 30, ~~2019~~2020 and December 31, ~~2018.~~2019. On the Eversource balance sheets, Common Shareholders' Equity was fully attributable to Eversource parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.

~~15.~~14. EARNINGS PER SHARE

Basic EPS is computed based upon the weighted average number of common shares outstanding during each period. Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards and the equity forward sale agreement, as if they were converted into outstanding common shares. The dilutive effect of unvested RSU and performance share awards, as well as the equity forward sale agreement, is calculated using the treasury stock method. RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied.

As described in Note ~~13,~~12, "Common Shares," earnings per share dilution, if any, related to the forward sale agreement ~~will be~~is determined under the treasury stock method until settlement of the forward sale agreement. Under this method, the number of Eversource common shares used in calculating diluted EPS is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreement less the number of shares that would be purchased by Eversource in the market (based on the average market price during the same reporting period) using the proceeds receivable upon settlement (based on the adjusted forward sale price at the end of that reporting period). Share dilution occurs when the average market price of Eversource's common shares is higher than the adjusted forward sale price.

For the nine months ended September 30, 2020, there were 52,747 antidilutive share awards excluded from the EPS computation, as their impact would have been antidilutive. Antidilutive shares pertained to a purchase option extended to underwriters in connection with Eversource's common share issuance on June 15, 2020. See Note 12, "Common Shares," for further information. There were 0 antidilutive share awards excluded from the computation for the three months ended September 30, 2020 and 2019 or the nine months ended September 30, 2019.

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


Eversource (Millions of Dollars, except share information)	For the Three Months Ended				For the Nine Months Ended				For the Three Months Ended				For the Nine Months Ended
Eversource (Millions of Dollars, except share information)	September 30, 2019		September 30, 2018		September 30, 2019		September 30, 2018		September 30, 2020		September 30, 2019		September 30, 2020		September 30, 2019
Net Income Attributable to Common Shareholders	$	318.9	$	289.4	$	659.0	$	801.7	$	346.3	$	318.9	$	933.2	$	659.0
Weighted Average Common Shares Outstanding:
Basic	324,037,169		317,360,110		320,442,253		317,367,252		343,076,614		324,037,169		337,375,172		320,442,253
Dilutive Effect of:
Share-Based Compensation Awards and Other	737,972		607,201		691,636		581,246		696,988		737,972		686,403		691,636
Equity Forward Sale Agreement	1,233,201		—		437,037		—		0		1,233,201		362,525		437,037
Total Dilutive Effect	1,971,173		607,201		1,128,673		581,246		696,988		1,971,173		1,048,928		1,128,673
Diluted	326,008,342		317,967,311		321,570,926		317,948,498		343,773,602		326,008,342		338,424,100		321,570,926
Basic EPS	$	0.98	$	0.91	$	2.06	$	2.53	$	1.01	$	0.98	$	2.77	$	2.06
Diluted EPS	$	0.98	$	0.91	$	2.05	$	2.52	$	1.01	$	0.98	$	2.76	$	2.05

~~16.~~

15. REVENUES

The following tables present operating revenues disaggregated by revenue source:

For the Three Months Ended September 30, 2019
Eversource
(Millions of Dollars)
Electric
Distribution Natural Gas
Distribution Electric
Transmission Water Distribution Other Eliminations Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential $ 1,041.4
$ 43.0
$ —
$ 40.0
$ —
$ —
$ 1,124.4
Commercial 736.6
41.6
—
17.8
—
(1.4 ) 794.6
Industrial 90.6
18.1
—
1.3
—
(3.2 ) 106.8
Total Retail Tariff Sales Revenues 1,868.6

102.7
—
59.1

—
(4.6 ) 2,025.8
Wholesale Transmission Revenues —
—
365.5
—
15.4
(300.7 ) 80.2
Wholesale Market Sales Revenues 33.1
5.5
—
1.3
—
—
39.9
Other Revenues from Contracts with Customers 12.3
0.5
3.1
1.7
242.7
(243.0 ) 17.3
Reserve for Revenues Subject to Refund 4.5
1.5
—
(0.8 ) —
—
5.2
Total Revenues from Contracts with Customers 1,918.5

110.2
368.6
61.3

258.1
(548.3 ) 2,168.4
Alternative Revenue Programs 6.7
(7.6 ) (20.9 ) 2.6
—
19.0
(0.2 )
Other Revenues ⁽¹⁾
6.4
0.8
0.1
0.3
—
—
7.6
Total Operating Revenues $ 1,931.6

$ 103.4
$ 347.8
$ 64.2

$ 258.1
$ (529.3 ) $ 2,175.8


	For the Nine Months Ended September 30, 2019																	For the Three Months Ended September 30, 2020
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution		Electric Transmission		Water Distribution			Other		Eliminations			Total		Electric Distribution		Natural Gas Distribution			Electric Transmission			Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	2,879.8		$	402.0	$	—	$	100.5		$	—	$	—		$	3,382.3	$	1,183.9	$	45.5		$	0		$	45.8		$	0	$	0		$	1,275.2
Commercial	2,002.0			254.9		—		48.1			—		(3.4		)	2,301.6		682.7		41.1			0			17.1			0		(1.4		)	739.5
Industrial	254.0			72.5		—		3.5			—		(8.7		)	321.3		91.0		17.5			0			1.3			0		(3.6		)	106.2
Total Retail Tariff Sales Revenues	5,135.8			729.4		—		152.1			—		(12.1		)	6,005.2		1,957.6		104.1			0			64.2			0		(5.0		)	2,120.9
Wholesale Transmission Revenues	—			—		971.6		—			43.7		(811.4		)	203.9		0		0			458.2			0			19.0		(365.6		)	111.6
Wholesale Market Sales Revenues	123.9			41.6		—		3.2			—		—			168.7		79.6		8.7			0			1.1			0		0			89.4
Other Revenues from Contracts with Customers	40.0			1.9		9.9		5.2			723.4		(725.2		)	55.2		18.4		0.8			3.2			1.8			303.3		(299.0		)	28.5
Reserve for Revenues Subject to Refund	(1.7		)	4.7		—		(1.9		)	—		—			1.1
Amortization of/(Reserve for) Revenues Subject to Refund																		2.3		0.5			0			(1.1		)	0		0			1.7
Total Revenues from Contracts with Customers	5,298.0			777.6		981.5		158.6			767.1		(1,548.7		)	6,434.1		2,057.9		114.1			461.4			66.0			322.3		(669.6		)	2,352.1
Alternative Revenue Programs	15.0			—		56.1		4.2			—		(50.8		)	24.5		1.7		(4.0		)	(72.3		)	(2.0		)	0		67.0			(9.6		)
Other Revenues ⁽¹⁾	14.2			2.3		0.3		0.7			—		—			17.5		0.7		0.1			0.2			0.1			0		0			1.1
Total Operating Revenues	$	5,327.2		$	779.9	$	1,037.9	$	163.5		$	767.1	$	(1,599.5	)	$	6,476.1	$	2,060.3	$	110.2		$	389.3		$	64.1		$	322.3	$	(602.6	)	$	2,343.6


																		For the Nine Months Ended September 30, 2020
Eversource (Millions of Dollars)																		Electric Distribution		Natural Gas Distribution			Electric Transmission			Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential																		$	3,063.7	$	399.6		$	0		$	113.2		$	0	$	0		$	3,576.5
Commercial																		1,815.7		243.5			0			47.7			0		(3.7		)	2,103.2
Industrial																		248.4		67.0			0			3.6			0		(10.1		)	308.9
Total Retail Tariff Sales Revenues																		5,127.8		710.1			0			164.5			0		(13.8		)	5,988.6
Wholesale Transmission Revenues																		0		0			1,177.9			0			55.6		(981.4		)	252.1
Wholesale Market Sales Revenues																		231.1		31.9			0			2.9			0		0			265.9
Other Revenues from Contracts with Customers																		56.4		2.5			9.9			5.6			845.1		(838.0		)	81.5
Amortization of/(Reserve for) Revenues Subject to Refund																		6.9		1.6			0			(2.8		)	0		0			5.7
Total Revenues from Contracts with Customers																		5,422.2		746.1			1,187.8			170.2			900.7		(1,833.2		)	6,593.8
Alternative Revenue Programs																		54.8		22.9			(52.7		)	(4.1		)	0		48.9			69.8
Other Revenues ⁽¹⁾																		4.9		1.0			0.5			0.5			0		0			6.9
Total Operating Revenues																		$	5,481.9	$	770.0		$	1,135.6		$	166.6		$	900.7	$	(1,784.3	)	$	6,670.5

For the Three Months Ended September 30, 2018
Eversource
(Millions of Dollars)
Electric
Distribution

Natural Gas
Distribution

Electric
Transmission
Water Distribution Other Eliminations Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential $ 1,111.7
$ 42.8
$ —
$ 41.2
$ —
$ —
$ 1,195.7
Commercial 789.6
40.8
—
17.9
—
(1.2 ) 847.1
Industrial 98.7
18.9
—
1.3
—
(2.6 ) 116.3
Total Retail Tariff Sales Revenues 2,000.0
102.5
—
60.4
—
(3.8 ) 2,159.1
Wholesale Transmission Revenues —
—
364.5
—
11.7
(300.2 ) 76.0
Wholesale Market Sales Revenues 48.8
11.4
—
1.3
—
—
61.5
Other Revenues from Contracts with Customers 20.2
(0.5 ) 3.1
1.9
212.9
(213.5 ) 24.1
Reserve for Revenues Subject to Refund 5.2
(3.5 ) —
(1.3 ) —
—
0.4
Total Revenues from Contracts with Customers 2,074.2
109.9
367.6
62.3
224.6
(517.5 ) 2,321.1
Alternative Revenue Programs (51.6 ) (1.5 ) (37.0 ) 1.1
—
33.8
(55.2 )
Other Revenues 4.8
0.6
—
0.1
—
—
5.5
Total Operating Revenues $ 2,027.4
$ 109.0
$ 330.6
$ 63.5
$ 224.6
$ (483.7 ) $ 2,271.4

For the Nine Months Ended September 30, 2018
Eversource
(Millions of Dollars)
Electric
Distribution

Natural Gas
Distribution

Electric
Transmission
Water Distribution Other Eliminations Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential $ 2,900.4
$ 395.9
$ —
$ 100.9
$ —
$ —
$ 3,397.2
Commercial 2,023.0
245.4
—
47.9
—
(3.4 ) 2,312.9
Industrial 268.6
71.9
—
3.4
—
(7.5 ) 336.4
Total Retail Tariff Sales Revenues 5,192.0
713.2
—
152.2
—
(10.9 ) 6,046.5
Wholesale Transmission Revenues —
—
988.9
—
34.4
(826.9 ) 196.4
Wholesale Market Sales Revenues 141.4
41.4
—
3.1
—
—
185.9
Other Revenues from Contracts with Customers 54.4
(1.4 ) 9.4
5.4
658.1
(659.8 ) 66.1
Reserve for Revenues Subject to Refund (21.2 ) (11.5 ) —
(3.3 ) —
—
(36.0 )
Total Revenues from Contracts with Customers 5,366.6
741.7
998.3
157.4
692.5
(1,497.6 ) 6,458.9
Alternative Revenue Programs (57.2 ) (3.2 ) (45.3 ) 3.7
—
41.5
(60.5 )
Other Revenues 12.4
2.0
—
0.4
—
—
14.8
Total Operating Revenues $ 5,321.8
$ 740.5
$ 953.0
$ 161.5
$ 692.5
$ (1,456.1 ) $ 6,413.2


	For the Three Months Ended September 30, 2019									For the Three Months Ended September 30, 2018									For the Three Months Ended September 30, 2019
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Eversource (Millions of Dollars)																			Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	513.6		$	374.4		$	153.4		$	539.6		$	414.8		$	157.3		$	1,041.4		$	43.0		$	0		$	40.0		$	0	$	0		$	1,124.4
Commercial	247.0			406.1			84.1			259.0			443.8			87.3			736.6			41.6			0			17.8			0		(1.4		)	794.6
Industrial	37.4			32.4			20.8			39.4			38.0			21.3			90.6			18.1			0			1.3			0		(3.2		)	106.8
Total Retail Tariff Sales Revenues	798.0			812.9			258.3			838.0			896.6			265.9			1,868.6			102.7			0			59.1			0		(4.6		)	2,025.8
Wholesale Transmission Revenues	175.2			132.9			57.4			179.1			128.3			57.1			0			0			365.5			0			15.4		(300.7		)	80.2
Wholesale Market Sales Revenues	13.8			14.4			4.9			13.3			18.1			17.4			33.1			5.5			0			1.3			0		0			39.9
Other Revenues from Contracts with Customers	9.0			3.1			4.0			9.3			10.3			4.0			12.3			0.5			3.1			1.7			242.7		(243.0		)	17.3
Reserve for Revenues Subject to Refund	—			—			4.5			8.3			—			(3.1		)
Amortization of/(Reserve for) Revenues Subject to Refund																			4.5			1.5			0			(0.8		)	0		0			5.2
Total Revenues from Contracts with Customers	996.0			963.3			329.1			1,048.0			1,053.3			341.3			1,918.5			110.2			368.6			61.3			258.1		(548.3		)	2,168.4
Alternative Revenue Programs	(15.2		)	9.8			(8.8		)	(64.3		)	(15.4		)	(8.9		)	6.7			(7.6		)	(20.9		)	2.6			0		19.0			(0.2		)
Other Revenues ⁽¹⁾	4.1			1.8			0.6			2.8			1.8			0.2			6.4			0.8			0.1			0.3			0		0			7.6
Eliminations	(131.0		)	(96.2		)	(40.5		)	(121.5		)	(100.2		)	(42.4		)
Total Operating Revenues	$	853.9		$	878.7		$	280.4		$	865.0		$	939.5		$	290.2		$	1,931.6		$	103.4		$	347.8		$	64.2		$	258.1	$	(529.3	)	$	2,175.8

	For the Nine Months Ended September 30, 2019									For the Nine Months Ended September 30, 2018
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
																			For the Nine Months Ended September 30, 2019
Eversource (Millions of Dollars)																			Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other		Eliminations			Total
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	1,426.9		$	1,027.8		$	425.1		$	1,410.0		$	1,071.6		$	418.8		$	2,879.8		$	402.0		$	0		$	100.5		$	0	$	0		$	3,382.3
Commercial	708.4			1,058.3			236.8			702.2			1,083.8			238.4			2,002.0			254.9			0			48.1			0		(3.4		)	2,301.6
Industrial	105.8			90.1			58.1			111.8			96.9			59.9			254.0			72.5			0			3.5			0		(8.7		)	321.3
Total Retail Tariff Sales Revenues	2,241.1			2,176.2			720.0			2,224.0			2,252.3			717.1			5,135.8			729.4			0			152.1			0		(12.1		)	6,005.2
Wholesale Transmission Revenues	445.9			383.1			142.6			469.8			367.7			151.4			0			0			971.6			0			43.7		(811.4		)	203.9
Wholesale Market Sales Revenues	39.6			55.9			28.4			34.3			56.4			52.3			123.9			41.6			0			3.2			0		0			168.7
Other Revenues from Contracts with Customers	27.0			13.2			11.8			25.0			27.9			11.4			40.0			1.9			9.9			5.2			723.4		(725.2		)	55.2
Reserve for Revenues Subject to Refund	—			—			(1.7		)	(8.3		)	(3.7		)	(9.2		)
(Reserve for)/Amortization of Revenues Subject to Refund																			(1.7		)	4.7			0			(1.9		)	0		0			1.1
Total Revenues from Contracts with Customers	2,753.6			2,628.4			901.1			2,744.8			2,700.6			923.0			5,298.0			777.6			981.5			158.6			767.1		(1,548.7		)	6,434.1
Alternative Revenue Programs	45.6			19.1			6.4			(68.4		)	(15.6		)	(18.5		)	15.0			0			56.1			4.2			0		(50.8		)	24.5
Other Revenues ⁽¹⁾	7.9			5.2			1.4			6.5			5.1			0.8			14.2			2.3			0.3			0.7			0		0			17.5
Eliminations	(363.1		)	(294.5		)	(111.1		)	(338.0		)	(289.8		)	(112.6		)
Total Operating Revenues	$	2,444.0		$	2,358.2		$	797.8		$	2,344.9		$	2,400.3		$	792.7		$	5,327.2		$	779.9		$	1,037.9		$	163.5		$	767.1	$	(1,599.5	)	$	6,476.1



	For the Three Months Ended September 30, 2020									For the Three Months Ended September 30, 2019
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	608.7		$	415.4		$	159.8		$	513.6		$	374.4		$	153.4
Commercial	244.7			358.3			80.1			247.0			406.1			84.1
Industrial	38.0			30.6			22.4			37.4			32.4			20.8
Total Retail Tariff Sales Revenues	891.4			804.3			262.3			798.0			812.9			258.3
Wholesale Transmission Revenues	233.3			153.1			71.8			175.2			132.9			57.4
Wholesale Market Sales Revenues	60.0			12.1			7.5			13.8			14.4			4.9
Other Revenues from Contracts with Customers	8.1			10.5			3.7			9.0			3.1			4.0
Amortization of Revenues Subject to Refund	0			0			2.3			0			0			4.5
Total Revenues from Contracts with Customers	1,192.8			980.0			347.6			996.0			963.3			329.1
Alternative Revenue Programs	(65.0		)	8.2			(13.8		)	(15.2		)	9.8			(8.8		)
Other Revenues ⁽¹⁾	0.2			0.7			0			4.1			1.8			0.6
Eliminations	(133.7		)	(113.5		)	(50.1		)	(131.0		)	(96.2		)	(40.5		)
Total Operating Revenues	$	994.3		$	875.4		$	283.7		$	853.9		$	878.7		$	280.4

	For the Nine Months Ended September 30, 2020									For the Nine Months Ended September 30, 2019
(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	1,567.9		$	1,057.9		$	437.9		$	1,426.9		$	1,027.8		$	425.1
Commercial	670.4			921.3			225.3			708.4			1,058.3			236.8
Industrial	105.3			82.1			61.0			105.8			90.1			58.1
Total Retail Tariff Sales Revenues	2,343.6			2,061.3			724.2			2,241.1			2,176.2			720.0
Wholesale Transmission Revenues	576.5			430.3			171.1			445.9			383.1			142.6
Wholesale Market Sales Revenues	163.9			39.8			27.4			39.6			55.9			28.4
Other Revenues from Contracts with Customers	25.1			32.4			10.9			27.0			13.2			11.8
Amortization of/(Reserve for) Revenues Subject to Refund	0			0			6.9			0			0			(1.7		)
Total Revenues from Contracts with Customers	3,109.1			2,563.8			940.5			2,753.6			2,628.4			901.1
Alternative Revenue Programs	(27.8		)	31.1			(1.2		)	45.6			19.1			6.4
Other Revenues ⁽¹⁾	2.0			2.8			0.6			7.9			5.2			1.4
Eliminations	(371.9		)	(327.5		)	(124.6		)	(363.1		)	(294.5		)	(111.1		)
Total Operating Revenues	$	2,711.4		$	2,270.2		$	815.3		$	2,444.0		$	2,358.2		$	797.8

⁽¹⁾

Other Revenues include certain fees charged to customers ~~which~~that are not considered revenue from contracts with customers. Other revenues also ~~includes~~include lease revenues under lessor accounting guidance of $1.1 million (including $0.2 million at CL&P and $0.7 million at NSTAR Electric) and $1.2 million ~~at Eversource,~~(including $0.3 million at CL&P and $0.7 million at NSTAR ~~Electric~~Electric) for the three months ended September 30, 2020 and 2019, respectively, and $3.2 million (including $0.6 million at CL&P and $2.1 million at NSTAR Electric) and $3.4 million ~~at Eversource,~~(including $0.7 million at CL&P and $2.0 million at NSTAR ~~Electric~~Electric) for the nine months ended September 30, 2020 and 2019, respectively.

CL&P, NSTAR Electric, Yankee Gas, NSTAR Gas and the Connecticut water distribution business each have a revenue decoupling mechanism approved by a regulatory commission. The revenue decoupling mechanisms mitigate the impact of lower demand and resulting lost sales revenues by replacing actual customer usage with a fixed annual revenue stream, each of which is reconciled each year as part of our annual decoupling filing in each respective jurisdiction. These revenue decoupling mechanisms qualify as alternative revenue programs in accordance with accounting guidance for rate-regulated operations. The increase in Eversource's electric and natural gas distribution segment revenues from Alternative Revenue Programs for the nine months ended September 30, 2020, as compared to the nine months ended September 30, 2019, was primarily the result of a higher decoupling deferral adjustment driven by lower distribution sales volumes in 2020. The decoupling deferral adjustment to revenues is recorded as a regulatory tracker mechanism within Regulatory Assets on the balance sheets.

~~17.~~

16. SEGMENT INFORMATION

Eversource is organized into the Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reportable segments and Other based on a combination of factors, including the characteristics of each segments' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates. These reportable segments represent substantially all of Eversource's total consolidated revenues. Revenues from the sale of electricity, natural gas and water primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer. The Electric Distribution reportable segment includes the results of ~~PSNH's generation facilities prior to sales in January and August 2018, and~~ NSTAR Electric's solar power facilities. Eversource's reportable segments are determined based upon the level at which Eversource's chief operating decision maker assesses performance and makes decisions about the allocation of company resources.

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) Eversource Water Ventures, Inc., parent company of Aquarion, ~~and~~ 5) the results of other unregulated subsidiaries, which are not part of its core ~~business. In addition, Other in the tables below includes~~business, and 6) Eversource parent's equity ownership interests that are not consolidated, which primarily include the offshore wind business, a natural gas pipeline owned by Enbridge, Inc., ~~the offshore wind business,~~and a renewable energy investment ~~fund, and 2 companies that transmit hydroelectricity imported from the Hydro-Quebec system in Canada.~~ fund.

In the ordinary course of business, Yankee Gas and NSTAR Gas purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline project described above. These affiliate transaction costs total ~~approximately~~ $62.5 million annually and are classified as Purchased Power, Fuel and Transmission on the Eversource statements of income.

Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has 1 reportable segment.

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 and PBOP expense.

Eversource's segment information is as follows:


	For the Three Months Ended September 30, 2019																					For the Three Months Ended September 30, 2020
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total			Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues	$	1,931.6		$	103.4		$	347.8		$	64.2		$	258.1		$	(529.3	)	$	2,175.8		$	2,060.3		$	110.2		$	389.3		$	64.1		$	322.3		$	(602.6	)	$	2,343.6
Depreciation and Amortization	(188.4		)	(16.1		)	(64.3		)	(11.1		)	(17.2		)	0.6			(296.5		)	(182.0		)	(14.8		)	(70.6		)	(10.8		)	(24.1		)	0.3			(302.0		)
Other Operating Expenses	(1,448.2		)	(99.3		)	(159.6		)	(25.5		)	(275.9		)	638.4			(1,370.1		)	(1,577.0		)	(104.2		)	(120.6		)	(10.2		)	(271.5		)	603.1			(1,480.4		)
Operating Income/(Loss)	$	295.0		$	(12.0	)	$	123.9		$	27.6		$	(35.0	)	$	109.7		$	509.2		$	301.3		$	(8.8	)	$	198.1		$	43.1		$	26.7		$	0.8		$	561.2
Interest Expense	$	(53.2	)	$	(11.7	)	$	(33.6	)	$	(8.9	)	$	(41.7	)	$	13.9		$	(135.2	)	$	(53.3	)	$	(10.1	)	$	(31.1	)	$	(8.0	)	$	(38.7	)	$	7.1		$	(134.1	)
Other Income/(Loss), Net	13.9			—			61.4			(0.2		)	497.0			(545.1		)	27.0
Other Income, Net																						16.0			0.7			6.9			1.6			387.0			(383.0		)	29.2
Net Income/(Loss) Attributable to Common Shareholders	197.3			(17.1		)	107.5			17.5			435.2			(421.5		)	318.9			205.5			(14.0		)	125.6			23.1			381.2			(375.1		)	346.3

	For the Nine Months Ended September 30, 2019																					For the Nine Months Ended September 30, 2020
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total			Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues	$	5,327.2		$	779.9		$	1,037.9		$	163.5		$	767.1		$	(1,599.5	)	$	6,476.1		$	5,481.9		$	770.0		$	1,135.6		$	166.6		$	900.7		$	(1,784.3	)	$	6,670.5
Depreciation and Amortization	(517.6		)	(56.0		)	(188.0		)	(35.0		)	(45.6		)	1.7			(840.5		)	(490.0		)	(55.1		)	(206.8		)	(33.1		)	(68.1		)	1.2			(851.9		)
Impairment of Northern Pass Transmission	—			—			(239.6		)	—			—			—			(239.6		)
Other Operating Expenses	(4,166.8		)	(620.4		)	(366.9		)	(75.4		)	(719.8		)	1,708.2			(4,241.1		)	(4,309.9		)	(592.0		)	(338.5		)	(60.7		)	(771.4		)	1,787.9			(4,284.6		)
Operating Income	$	642.8		$	103.5		$	243.4		$	53.1		$	1.7		$	110.4		$	1,154.9		$	682.0		$	122.9		$	590.3		$	72.8		$	61.2		$	4.8		$	1,534.0
Interest Expense	$	(153.3	)	$	(35.4	)	$	(94.5	)	$	(26.2	)	$	(130.3	)	$	40.0		$	(399.7	)	$	(160.7	)	$	(32.1	)	$	(93.8	)	$	(25.1	)	$	(119.0	)	$	27.6		$	(403.1	)
Other Income, Net	44.2			1.1			78.2			0.2			813.7			(833.6		)	103.8			44.9			2.5			22.7			1.7			1,161.7			(1,149.9		)	83.6
Net Income Attributable to Common Shareholders	422.7			57.6			138.4			26.3			697.2			(683.2		)	659.0			450.6			73.8			381.8			35.6			1,108.9			(1,117.5		)	933.2
Cash Flows Used for Investments in Plant	861.0			327.8			686.7			79.9			173.6			—			2,129.0			781.2			322.8			732.4			84.0			181.2			0			2,101.6

For the Three Months Ended September 30, 2018
Eversource
(Millions of Dollars)
Electric
Distribution

Natural Gas
Distribution

Electric
Transmission
Water Distribution Other Eliminations Total
Operating Revenues $ 2,027.4
$ 109.0
$ 330.6
$ 63.5
$ 224.6
$ (483.7 ) $ 2,271.4
Depreciation and Amortization (206.1 ) (13.9 ) (58.3 ) (11.7 ) (12.0 ) 0.6
(301.4 )
Other Operating Expenses (1,562.2 ) (102.4 ) (96.7 ) (25.5 ) (200.9 ) 483.7
(1,504.0 )
Operating Income/(Loss) $ 259.1
$ (7.3 ) $ 175.6
$ 26.3
$ 11.7
$ 0.6
$ 466.0
Interest Expense $ (52.4 ) $ (11.3 ) $ (30.3 ) $ (8.5 ) $ (30.5 ) $ 7.8
$ (125.2 )
Other Income, Net 32.2
1.5
9.0
0.7
251.7
(278.4 ) 16.7
Net Income/(Loss) Attributable to Common Shareholders 173.8
(12.6 ) 109.5
17.6
271.1
(270.0 ) 289.4


	For the Nine Months Ended September 30, 2018																					For the Three Months Ended September 30, 2019
Eversource (Millions of Dollars)	Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total			Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues	$	5,321.8		$	740.5		$	953.0		$	161.5		$	692.5		$	(1,456.1	)	$	6,413.2		$	1,931.6		$	103.4		$	347.8		$	64.2		$	258.1		$	(529.3	)	$	2,175.8
Depreciation and Amortization	(486.0		)	(59.6		)	(171.8		)	(34.6		)	(35.9		)	1.7			(786.2		)	(188.4		)	(16.1		)	(64.3		)	(11.1		)	(17.2		)	0.6			(296.5		)
Other Operating Expenses	(4,238.6		)	(585.7		)	(268.7		)	(73.9		)	(617.2		)	1,457.0			(4,327.1		)	(1,448.2		)	(99.3		)	(159.6		)	(25.5		)	(275.9		)	638.4			(1,370.1		)
Operating Income/(Loss)																						$	295.0		$	(12.0	)	$	123.9		$	27.6		$	(35.0	)	$	109.7		$	509.2
Interest Expense																						$	(53.2	)	$	(11.7	)	$	(33.6	)	$	(8.9	)	$	(41.7	)	$	13.9		$	(135.2	)
Other Income/(Loss), Net																						13.9			0			61.4			(0.2		)	497.0			(545.1		)	27.0
Net Income/(Loss) Attributable to Common Shareholders																						197.3			(17.1		)	107.5			17.5			435.2			(421.5		)	318.9

																						For the Nine Months Ended September 30, 2019
Eversource (Millions of Dollars)																						Electric Distribution			Natural Gas Distribution			Electric Transmission			Water Distribution			Other			Eliminations			Total
Operating Revenues																						$	5,327.2		$	779.9		$	1,037.9		$	163.5		$	767.1		$	(1,599.5	)	$	6,476.1
Depreciation and Amortization																						(517.6		)	(56.0		)	(188.0		)	(35.0		)	(45.6		)	1.7			(840.5		)
Impairment of Northern Pass Transmission																						0			0			(239.6		)	0			0			0			(239.6		)
Other Operating Expenses																						(4,166.8		)	(620.4		)	(366.9		)	(75.4		)	(719.8		)	1,708.2			(4,241.1		)
Operating Income	$	597.2		$	95.2		$	512.5		$	53.0		$	39.4		$	2.6		$	1,299.9		$	642.8		$	103.5		$	243.4		$	53.1		$	1.7		$	110.4		$	1,154.9
Interest Expense	$	(152.0	)	$	(33.7	)	$	(89.9	)	$	(25.5	)	$	(94.8	)	$	23.2		$	(372.7	)	$	(153.3	)	$	(35.4	)	$	(94.5	)	$	(26.2	)	$	(130.3	)	$	40.0		$	(399.7	)
Other Income/(Loss), Net	70.9			5.1			26.7			(0.4		)	913.8			(915.4		)	100.7
Other Income, Net																						44.2			1.1			78.2			0.2			813.7			(833.6		)	103.8
Net Income Attributable to Common Shareholders	379.3			50.2			329.6			26.3			905.9			(889.6		)	801.7			422.7			57.6			138.4			26.3			697.2			(683.2		)	659.0
Cash Flows Used for Investments in Plant	717.4			245.5			735.8			68.1			118.3			—			1,885.1			861.0			327.8			686.7			79.9			173.6			0			2,129.0

The following table summarizes Eversource's segmented total assets:



Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations			Total
As of September 30, 2020	$	23,864.7	$	4,579.9	$	11,469.7	$	2,332.0	$	22,230.1	$	(20,969.1	)	$	43,507.3
As of December 31, 2019	22,541.9		4,345.5		10,904.0		2,351.7		20,469.6		(19,488.8		)	41,123.9

Eversource
(Millions of Dollars)
Electric
Distribution

Natural Gas
Distribution
Electric
Transmission Water Distribution Other Eliminations Total
As of September 30, 2019 $ 21,999.4
$ 4,103.5
$ 10,666.9
$ 2,311.9
$ 19,137.8
$ (18,494.1 ) $ 39,725.4
As of December 31, 2018 21,389.1
3,904.9
10,285.0
2,253.0
17,874.2
(17,464.9 ) 38,241.3

~~For further information regarding~~

17. ACQUISITION OF ASSETS OF COLUMBIA GAS OF MASSACHUSETTS

On October 9, 2020, Eversource acquired certain assets that comprised NiSource’s local natural gas distribution business in Massachusetts, which was previously doing business as CMA, pursuant to an asset purchase agreement (the Agreement) entered into on February 26, 2020 between Eversource and NiSource Inc. The cash purchase price was $1.1 billion plus a target working capital amount, which is subject to adjustment to reflect actual working capital as of the ~~2019 impairment~~closing date. Eversource financed the asset acquisition through a combination of ~~NPT, see Note 1C, "Summary~~debt and equity issuances in a ratio that was consistent with our consolidated capital structure. The natural gas distribution assets acquired from CMA were assigned to Eversource Gas Company of ~~Significant Accounting Policies - Impairment~~Massachusetts, an indirect wholly-owned subsidiary of ~~Northern Pass Transmission,"~~Eversource formed in 2020. The LNG assets acquired from CMA were assigned to Hopkinton LNG Corp. Eversource Gas Company of Massachusetts distributes natural gas to approximately 330,000 residential, commercial and industrial customers with over 5,000 miles of natural gas distribution pipeline across more than 60 communities in Massachusetts, adding to the approximately 300,000 natural gas customers that Eversource already serves in Massachusetts.

The transaction was approved by the DPU, the Maine Public Utilities Commission, the FERC, and the Federal Communications Commission. The relevant review period under the Hart-Scott-Rodino Act expired. On October 7, 2020, the DPU also approved a rate settlement with the Massachusetts Attorney General’s Office, the DOER, and the Low-Income Weatherization and Fuel Assistance Program Network.

The liabilities assumed by Eversource under the Agreement specifically excluded any liabilities (past or future) arising out of, or related to, the fires and explosions that occurred on September 13, 2018 in Lawrence, Andover and North Andover, Massachusetts related to the delivery of natural gas by CMA, including certain subsequent events, all as described and in the DPU's Order on Scope dated December 23, 2019 (D.P.U. 19-141) (the Greater Lawrence Incident or GLI). The liabilities assumed also excluded any further emergency events prior to the closing of the acquisition related to the restoration and reconstruction with respect to the GLI, including any losses arising out of, or related to, any litigation, demand, cause of action, claim, suit, investigation, proceeding, indemnification agreements or rights. Eversource did not assume any of CMA's or NiSource Inc.'s debt obligations or notes payable.

Due to the limited amount of time between the asset acquisition date and the Company’s filing of its Form 10-Q for the quarter ended September 30, 2020, the initial accounting and development of pro-forma financial ~~statements.~~information for the asset acquisition are incomplete, and therefore certain disclosures required under business combinations accounting guidance have been omitted. The Company intends to include these disclosures in its 2020 Annual Report on Form 10-K.

EVERSOURCE ENERGY AND SUBSIDIARIES

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

The following discussion and analysis should be read in conjunction with our unaudited condensed consolidated financial statements and related combined notes included in this combined Quarterly Report on Form 10-Q, the combined Quarterly Report on Form 10-Q for the quarters ended March 31, ~~2019~~2020 and June 30, ~~2019,~~2020, as well as the Eversource ~~2018~~2019 combined Annual Report on Form 10-K. References in this combined Quarterly Report on Form 10-Q to "Eversource," the "Company," "we," "us," and "our" refer to Eversource Energy and its consolidated subsidiaries. All per-share amounts are reported on a diluted basis. The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P 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, 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. Our earnings discussion also includes a non-GAAP financial ~~measure~~measures referencing our 2020 earnings and EPS excluding certain acquisition costs and our second quarter 2019 earnings and EPS excluding the impairment charge for the NPT project.

We use these non-GAAP financial measures to evaluate and provide details of earnings results by business and to more fully compare and explain our 2020 and 2019 results without including ~~the impact of the NPT impairment charge.~~these items. We believe the acquisition costs and the NPT impairment charge isare not indicative of our ongoing costs and performance. Due to the nature and significance of ~~the impairment charge~~these items on Net Income Attributable to Common Shareholders, we believe that the non-GAAP presentation is a more meaningful representation of our financial performance and provides additional and useful information to readers of this report in analyzing historical and future performance of our business. These non-GAAP financial measures should not be considered as ~~an alternative~~alternatives to reported Net Income Attributable to Common Shareholders or EPS determined in accordance with GAAP as ~~an indicator~~indicators of operating performance.

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:

cyberattacks or breaches, including those resulting in the compromise of the confidentiality of our proprietary information and the personal information of our customers,

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

the negative impacts of the novel coronavirus (COVID-19) pandemic on our customers, vendors, employees, regulators, and operations,

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

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

acts of war or terrorism, physical attacks or grid disturbances that may damage and disrupt our electric transmission and electric, natural gas, and water distribution systems,

~~ability or inability to commence and complete our major strategic development projects and opportunities,~~

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

substandard performance of third-party suppliers and service providers,

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

changes in business conditions, which could include disruptive technology or development of alternative energy sources related to our current or future business model,

~~increased conservation measures of customers and development of alternative energy sources,~~

contamination of, or disruption in, our water supplies,

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

~~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,~~

changes in laws, regulations or regulatory policy, including compliance with environmental laws and regulations,

changes in accounting standards and financial reporting regulations,

actions of rating agencies, and

other presently unknown or unforeseen factors.

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

All such factors are difficult to predict and contain uncertainties that may materially affect our actual results, many of which are beyond our control. You should not place undue reliance on the forward-looking statements, as each speaks only as of the date on which such statement is made, and, except as required by federal securities laws, we undertake no obligation to update any forward-looking statement or statements to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events.

New factors emerge from time to time and it is not possible for us to predict all of such factors, nor can we assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements. For more information, see Item 1A, Risk Factors, included in this combined Quarterly Report on Form 10-Q and in

Eversource's ~~2018~~2019 combined Annual Report on Form 10-K. This combined Quarterly Report on Form 10-Q and Eversource's ~~2018~~2019 combined Annual Report on Form 10-K also describe material contingencies and critical accounting policies in the accompanying Management's Discussion and Analysis of Financial Condition and Results of Operations and Combined Notes to Financial Statements. We encourage you to review these items.

Financial Condition and Business Analysis

Executive Summary

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

Earnings Overview and Future Outlook:

•

We earned $346.3 million, or $1.01 per share, in the third quarter of 2020, and $933.2 million, or $2.76 per share, in the first nine months of 2020, compared with $318.9 million, or $0.98 per share, in the third quarter of 2019, and $659.0 million, or $2.05 per share, in the first nine months of 2019. Our 2020 results include after-tax acquisition costs related to our purchase of the assets of Columbia Gas of Massachusetts (CMA) of $5.3 million, or $0.01 per share, in the third quarter of 2020, and $12.8 million, or $0.04 per share, in the first nine months of 2020. Results for the first nine months of 2019 include an after-tax impairment charge of $204.4 million, or $0.64 per share, related to our former investment in the NPT project. Excluding those acquisition costs in 2020, we earned $351.6 million, or $1.02 per share, in the third quarter of 2020, and $946.0 million, or $2.80 per share, in the first nine months of 2020. Excluding the NPT impairment charge, we earned $863.4 million, or $0.98 per share, in the third quarter of 2019, and $659.0 million, or $2.05 per share, in the first nine months of 2019, compared with $289.4 million, or $0.91 per share, in the third quarter of 2018, and $801.7 million, or $2.52 per share, in the first nine months of 2018. Results for the first nine months of 2019 include an after-tax impairment charge of $204.4 million, or $0.64 per share, related to our investment in the NPT project. Excluding that impairment charge, we earned ~~$863.4 million~~, or $2.69 per share, in the first nine months of 2019.

Our electric distribution segment earned $205.5 million, or $0.60 per share, in the third quarter of 2020, and $450.6 million, or $1.33 per share, in the first nine months of 2020, compared with $197.3 million, or $0.61 per share, in the third quarter of 2019, and $422.7 million, or $1.32 per share, in the first nine months of ~~2019, compared with $173.8~~2019. Our natural gas distribution segment had a net loss of $14.0 million, or ~~$0.55~~$0.04 per share, in the third quarter of ~~2018,~~2020, and ~~$379.3~~earnings of $73.8 million, or ~~$1.19~~$0.22 per share, in the first nine months of ~~2018. Our natural gas distribution segment had~~2020, compared with a net loss of $17.1 million, or $0.05 per share, in the third quarter of 2019, and earnings of $57.6 million, or $0.18 per share, in the first nine months of ~~2019, compared with a net loss of $12.6~~2019. Our water distribution segment earned $23.1 million, or ~~$0.04~~$0.07 per share, in the third quarter of ~~2018,~~2020, and ~~earnings of $50.2~~$35.6 million, or ~~$0.16~~$0.11 per share, in the first nine months of ~~2018. Our water distribution segment earned~~2020, compared with $17.5 million, or $0.06 per share, in the third quarter of 2019, and $26.3 million, or $0.08 per share, in the first nine months of ~~2019, compared with $17.6~~2019.

Our electric transmission segment earned $125.6 million, or ~~$0.06~~$0.36 per share, in the third quarter of ~~2018,~~2020, and ~~$26.3~~$381.8 million, or ~~$0.08~~$1.13 per share, in the first nine months of ~~2018.~~

~~Our electric transmission segment earned~~2020, compared with $107.5 million, or $0.33 per share, in the third quarter of 2019, and $138.4 million, or $0.43 per share in the first nine months of ~~2019, compared with $109.5 million, or $0.34 per share, in the third quarter of 2018, and $329.6 million, or $1.04 per share, in the first nine months of 2018.~~2019. Excluding the after-tax NPT impairment charge of $204.4 million, or $0.64 per share, our electric transmission segment earned $342.8 million, or $1.07 per share, in the first nine months of 2019.

Eversource parent and other companies earned $6.1 million, or $0.02 per share, in the third quarter of 2020, and had a net loss of $8.6 million, or $0.03 per share, in the first nine months of 2020, compared with earnings of $13.7 million, or $0.03 per share, in the third quarter of 2019, and $14.0 million, or $0.04 per share, in the first nine months of ~~2019, compared with $1.1~~2019. Excluding acquisition costs, Eversource parent and other companies earned $11.4 million, or $0.03 per share, in the third quarter of ~~2018,~~2020, and ~~$16.3~~$4.2 million, or ~~$0.05~~$0.01 per share, in the first nine months of ~~2018.~~ 2020.

~~Excluding~~We reaffirm 2020 non-GAAP earnings guidance of between $3.60 per share and $3.70 per share, which excludes the ~~NPT impairment charge,~~impact of acquisition and integration costs related to our purchase of the assets of CMA, and our long-term EPS growth rate through 2024 from our regulated utility businesses of between 5 to 7 percent.

As of the date of our filing, the outbreak of COVID-19 has not resulted in significant financial or operational impacts. We believe that we have in place, or are developing, successful mechanisms with our state regulatory commissions that allow, or will allow, us to recover our incremental costs associated with COVID-19, which include uncollectible customer receivable expenses. We are continuing to closely monitor the COVID-19 pandemic, and we continue to ~~project non-GAAP 2019 earnings of between $3.40 per share and $3.50 per share.~~operate under our pandemic response plan.

Liquidity:

Cash flows provided by operating activities totaled $1.50 billion in the first nine months of 2020, compared with $1.49 billion in the first nine months of ~~2019, compared with $1.41~~2019. Investments in property, plant and equipment totaled $2.10 billion in the first nine months of ~~2018. Investments in property, plant and equipment totaled~~2020, compared with $2.13 billion in the first nine months of ~~2019,~~2019. Cash and Cash Equivalents totaled $730.0 million as of September 30, 2020, compared with ~~$1.89~~$15.4 million as of December 31, 2019. Our available borrowing capacity under our commercial paper programs totaled $2.04 billion inas of September 30, 2020.

In the first nine months of ~~2018. Cash totaled $22.7~~2020, we issued 11,960,000 common shares, which resulted in proceeds of $929.0 million, asnet of ~~September 30, 2019, compared with $108.1 million as of December 31, 2018.~~issuance costs.

In the ~~third quarter~~first nine months of ~~2019,~~2020, we issued ~~$475 million~~$2.36 billion of new long-term debt, consisting of ~~$200~~$1.55 billion by Eversource parent, $400 million by ~~CL&P, $200~~NSTAR Electric, $150 million by ~~Yankee~~PSNH, $190 million by NSTAR Gas and ~~$75~~$70 million by ~~NSTAR~~Yankee Gas. Proceeds from these new issuances were used primarily to ~~repay~~fund a portion of the purchase price for the CMA asset acquisition and to pay short-term borrowings ~~repay long-term debt~~ at ~~maturity~~Eversource parent, refinance investments in eligible green expenditures at NSTAR Electric, and to refinance existing indebtedness, fund capital expenditures and ~~working capital.~~for general corporate purposes at PSNH, NSTAR Gas and Yankee Gas.

~~Strategic:~~Strategic, Regulatory, Legislative and Other Items:

On October ~~23, 2019, NYSERDA announced~~9, 2020, Eversource completed the ~~execution~~acquisition of certain assets that comprised NiSource’s local natural gas distribution business in Massachusetts, CMA, for a ~~25-year agreement with the Sunrise Wind project to~~cash purchase Offshore Wind Renewable Energy Certificates (ORECs) from an 880 MW offshore wind facility. The project was selected on July 18, 2019 and will use a combination of lease areas from Bay State Wind and North East Offshore, and will sell ORECs to NYSERDA at a price of ~~$110.37 per MWh. Subject~~$1.1 billion plus a target working capital amount, which is subject to ~~Eversource’s and Ørsted's final investment decisions,~~adjustment to reflect actual working capital as of the ~~project is expected~~closing date. On October 7, 2020, the DPU approved the rate plan related to ~~be operational in 2024.~~the acquisition.

On ~~September 30, 2019, Eversource~~August 4, 2020, Tropical Storm Isaias caused catastrophic damage to our electric distribution system, which resulted in significant amounts and ~~Ørsted submitted several alternative bids, called Constitution Wind,~~durations of customer outages, primarily in Connecticut. In terms of customer outages, this storm was one of the worst in CL&P’s history. Management continues to ~~DEEP, in~~evaluate the storm restoration costs and believes our response to ~~Connecticut's offshore wind RFP~~the storm was prudent and expects the costs meet the criteria for ~~400 MW (and up~~specific cost recovery. As a result, management does not expect the storm costs to ~~2,000 MW). We currently expect~~have a ~~decision~~material impact on the results of operations of Eversource or CL&P. PURA has opened an investigation in Connecticut to review the preparation for and response of utilities to the storm. PURA will also investigate the prudence of costs incurred by CL&P to restore service as part of its response. CL&P expects to request recovery of these ~~proposals~~deferred storm costs through its regulatory recovery process before PURA in ~~late November 2019.~~2021.

New Connecticut legislation enacted on October 8, 2020 requires, among other things, PURA to open a proceeding by June 1, 2021 to begin to evaluate and eventually implement performance based regulation for electric distribution companies; extends deadlines for PURA to issue final decisions in rate cases, change of control transactions and financing proceedings to be more consistent with timeframes in many other U.S. jurisdictions; increases the maximum potential penalty for noncompliance with storm performance standards from 2.5 percent to 4 percent of annual electric distribution company revenue; and directs PURA to open a proceeding by January 1, 2021 to evaluate and decide when bill credits should be paid to electric customers who lose service in future storms, including when waivers of these criteria will be granted to utilities. This law has no impact on storm response, costs or impacts prior to July 1, 2021.

Impact of COVID-19

Operational: We provide a critical service to our customers and have taken extensive measures to maintain its safety and reliability. We have implemented our company-wide pandemic plan, which guides our emergency response, business continuity, and the precautionary measures we are taking to ensure the safety, health, and well-being of our employees, our customers, and our communities. We continue to adjust our company-wide pandemic plan to address various scenarios, including reduced workforce levels and limited mutual aid in the event of a significant storm event, and have implemented protective measures to mitigate the impact of COVID-19 on our workforce. We have implemented work from home policies where appropriate, resulting in nearly half of our employees working remotely. For our employees performing essential functions that are required onsite, such as field crews and system operations, we have taken significant safety measures, including establishing social distancing measures, enabling critical operations to be shifted to different control center locations if necessary, and increasing facility sanitization efforts and the use of personal protective equipment. At this time, our workforce staffing levels continue to enable us to safely and reliably deliver our critical services to customers.

In mid-March, we suspended non-critical work inside customer premises, which included energy audits inside our customers’ homes and businesses. These activities resumed in early July with the implementation of new health and safety guidelines for the restart of energy efficiency services to customers. As of the date of our filing, we do not expect a significant impact on our 2020 energy efficiency program spending and efforts, which assumes the continuation of energy efficiency programs throughout the remainder of 2020.

We are also preparing for the re-entry of our employees working remotely. Our re-entry plan includes a multi-phase approach that is measured, cautious and gradual. The plan is informed by public health guidance with the safety of our employees and customers as our highest priority. We are in the early phases of our re-entry plan and have returned fewer than 100 remote employees back to the workplace. State and federal guidelines, external conditions, and critical business priorities continue to inform the pace of our re-entry plan. Significant health and safety measures and pandemic protocols, including social distancing requirements, the use of personal protective equipment, sanitization efforts and employee training, are in place for all employees currently working onsite and specific plans have been developed for our eventual re-entry to the workplace.

Among the states we serve, COVID-19 had initially spread in a rapid manner in Connecticut and Massachusetts during the outbreak that began in mid-March. Measures used to control it, such as social distancing and face coverings, are having a positive reduction in its spread. During the summer, these states had seen a decrease in the infection rate and daily confirmed cases, as well as more capacity in hospitals, and improved testing availability and contact tracing, as compared to the initial outbreak. However, currently in each of the states we serve, there has been an increase in the infection rate and daily confirmed cases, as compared to the lower summer levels.

Financial: Overall, our future financial position, results of operations, and cash flows could be negatively impacted by COVID-19 as it relates to the valuation of customer receivables, collectibility estimates and customer payment plans, elimination of late payment revenues, lower sales volumes primarily from PSNH's commercial and industrial customers, energy efficiency spending levels and incentives earned, and increased expenses for cleaning and supplies for personal protective equipment. Other potential negative financial impacts relate to market volatility on our equity and debt securities, access to, as well as cost of, capital resources, and the ability of various third-party vendors and suppliers to fulfill their obligations.

As of September 30, 2020, our allowance for uncollectible customer receivable balance of $295.0 million, of which $178.7 million relates to hardship accounts that are specifically recovered in rates charged to customers, adequately reflected the collection risk and net realizable value for our receivables. We continue to evaluate the adequacy of the uncollectible allowance based on an ongoing assessment of accounts receivable collections and customer payment trends, economic conditions, delinquency statistics, the impact on residential customer bills because of energy usage and change in rates, COVID-19 developments, including any potential federal legislation, and analysis of aging-based quantitative assessments. This evaluation has shown that our operating companies have experienced an increase in aged receivables and some lower cash collections from customers because of the moratorium on disconnections and the economic slowdown resulting from the COVID-19 pandemic. Based upon the evaluation performed, for the three and nine months ended September 30, 2020, we increased the allowance for uncollectible costs incurred as a result of COVID-19 by $11.3 million and $16.5 million, respectively. These COVID-19 related uncollectible amounts were deferred either as incremental regulatory costs or deferred through existing regulatory tracking mechanisms that recover uncollectible energy supply costs as we believe it is probable that these costs will ultimately be recovered from customers in rates. We believe that we have in place, or are developing, successful mechanisms with our state regulatory commissions that allow, or will allow, us to recover our incremental costs associated with COVID-19, which include uncollectible customer receivable expenses, while balancing the impact on our customers’ bills and our operating cash flows.

Beginning in March 2020, Connecticut, Massachusetts and New Hampshire established moratoriums on disconnections of residential and commercial customers for non-payment for utility service. In all three states, a moratorium for lower income hardship residential customers will remain in place through the normal state regulated winter moratorium that ends in the spring of 2021. In Connecticut, the moratorium for all remaining customers has expired, and on October 30, 2020, PURA denied a pending petition to extend the moratorium for non-hardship residential and small business customers. In Massachusetts, the moratorium on commercial utility disconnections ended on September 1, 2020 and the moratorium on residential non-hardship disconnections ends on November 15, 2020. In New Hampshire, the moratorium on residential and commercial utility disconnections ended on July 15, 2020.

We continue to work closely with our state regulatory commissions and consumer advocates on customer assistance measures, including payment plan options in order to mitigate the impact on customer rates in the future, as well as financial hardship and arrearage management programs for those customers who are unable to pay their utility bills. We developed these long-term solutions for customers in order to help minimize the extent of the impact of COVID-19 on customer receivable balances and customers’ affordability in light of the current financial impact they may experience. Our operating companies have also eliminated late payment charges at this time, with New Hampshire being the only state with a defined restart date of April 1, 2021.

As of September 30, 2020, net incremental costs as a result of COVID-19 that we have deferred totaled $15.1 million, of which $11.4 million was related to non-tracked uncollectible expense. In the third quarter and first nine months of 2020, incremental COVID-19 expenses that reduced pre-tax earnings totaled $2.1 million and $9.6 million, respectively, and related to facilities and fleet cleaning, sanitizing costs and supplies for personal protective equipment. For further information on Connecticut, Massachusetts and New Hampshire COVID-19-related regulatory developments, see "Regulatory Developments and Rate Matters - COVID-19 Regulatory Dockets" included in this Management’s Discussion and Analysis.

An extended economic slowdown has resulted in lower demand for electricity, natural gas and/or water by our commercial and industrial customers. However, fluctuations in retail sales volumes for CL&P, NSTAR Electric, Yankee Gas, NSTAR Gas, Eversource Gas Company of Massachusetts, and our Connecticut water distribution business do not materially impact earnings due to their respective state regulatory commission-approved distribution revenue decoupling mechanisms. Overall, our risk of exposure to lower demand and resulting lost sales revenues is limited as our regulated utilities, with the exception of PSNH, are under cost-of-service rates with revenue decoupling mechanisms and a significant portion of uncollectible expenses are tracked for ultimate recovery. Our revenue decoupling mechanisms replace actual customer usage with a fixed annual revenue stream, and each is reconciled each year as part of our annual decoupling filing in each respective jurisdiction.

As of September 30, 2020, we did not identify indicators or triggering events for impairments to our goodwill, long-lived assets, available-for-sale debt securities, or equity method investment carrying values. As of the date of our filing, based on available information and the current market trends, we do not expect an impairment to these assets for the remainder of 2020.

We continue to monitor Eversource parent’s and our operating companies’ ability to access the global capital and credit markets. At the onset of the pandemic in the United States, liquidity in the commercial paper credit market began to deteriorate rapidly. However, federal legislative actions, including actions taken by the Federal Reserve, have provided sufficient liquidity and stabilization of the credit markets. An extended economic slowdown could result in Eversource parent and our operating companies finding difficulty in accessing necessary capital resources and incurring higher costs for those capital resources. As of the date of our filing, based on available information and the current market trends, we believe we will continue to have access to needed liquidity and capital resources to successfully execute our projected 2020 capital expenditures and strategies. We expect our existing borrowing availability under our commercial paper programs, our existing revolving credit facilities that serve to backstop those commercial paper programs, in addition to access to the debt and equity markets, will be sufficient to meet our future liquidity and capital resource needs.

In addition, the successful execution of our timeline for developing our offshore wind projects is based on several factors, including state and federal siting and permitting approvals. We are developing mitigation plans to address permitting delays due to COVID-19 restrictions on our offshore wind projects. For further information, see "Business Development and Capital Expenditures - Offshore Wind Business" included in this Management’s Discussion and Analysis.

Pension and PBOP plan assets and obligations are remeasured annually using a December 31^st measurement date. Our future pension and PBOP obligations are highly dependent on benefit plan asset returns, interest rates, and discount rates, all of which could be materially impacted by an extended economic slowdown. Should these financial metrics be negatively impacted by COVID-19 as of December 31, 2020, it could result in the underperformance of our pension and PBOP plan investments, an increase in pension and PBOP obligations and employee benefit plan costs, and in a minimum pension funding requirement due by March 31, 2022 for the 2021 Plan year. We continue to monitor federal legislative pension developments that could provide additional pension funding relief.As of the date of our filing, we are unable to determine whether the pandemic will have a material impact to our future pension and PBOP obligations and plan costs and minimum funding requirements. Our Massachusetts utilities recover qualified pension and PBOP expenses through a rate reconciling mechanism that fully tracks the change in net pension and PBOP expenses each year. Our electric transmission companies' rates provide for an annual true-up of estimated to actual costs, which include pension and PBOP expenses.

Earnings Overview

Consolidated: Below is 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 Three Months Ended September 30,								For the Nine Months Ended September 30,										For the Three Months Ended September 30,										For the Nine Months Ended September 30,
	2019				2018				2019						2018				2020						2019				2020						2019
(Millions of Dollars, Except Per Share Amounts)	Amount		Per Share		Amount		Per Share		Amount			Per Share			Amount		Per Share		Amount			Per Share			Amount		Per Share		Amount			Per Share			Amount			Per Share
Net Income Attributable to Common Shareholders (GAAP)	$	318.9	$	0.98	$	289.4	$	0.91	$	659.0		$	2.05		$	801.7	$	2.52	$	346.3		$	1.01		$	318.9	$	0.98	$	933.2		$	2.76		$	659.0		$	2.05

Regulated Companies	$	305.2	$	0.95	$	288.3	$	0.91	$	849.4		$	2.65		$	785.4	$	2.47
Eversource Parent and Other Companies	13.7		0.03		1.1		—		14.0			0.04			16.3		0.05
Regulated Companies (non-GAAP)																			$	340.2		$	0.99		$	305.2	$	0.95	$	941.8		$	2.79		$	849.4		$	2.65
Eversource Parent and Other Companies (non-GAAP)																			11.4			0.03			13.7		0.03		4.2			0.01			14.0			0.04
Non-GAAP Earnings	$	318.9	$	0.98	$	289.4	$	0.91	$	863.4		$	2.69		$	801.7	$	2.52	$	351.6		$	1.02		$	318.9	$	0.98	$	946.0		$	2.80		$	863.4		$	2.69
Acquisition-Related Costs (after-tax) ⁽¹⁾																			(5.3		)	(0.01		)	—		—		(12.8		)	(0.04		)	—			—
Impairment of Northern Pass Transmission (after-tax)	—		—		—		—		(204.4		)	(0.64		)	—		—		—			—			—		—		—			—			(204.4		)	(0.64		)
Net Income Attributable to Common Shareholders (GAAP)	$	318.9	$	0.98	$	289.4	$	0.91	$	659.0		$	2.05		$	801.7	$	2.52	$	346.3		$	1.01		$	318.9	$	0.98	$	933.2		$	2.76		$	659.0		$	2.05

⁽¹⁾ These costs are associated with our acquisition of the assets of Columbia Gas of Massachusetts.

Regulated Companies: Our regulated companies comprise the electric distribution, electric transmission, natural gas distribution and water distribution segments. A summary of our segment earnings and EPS is as follows:


	For the Three Months Ended September 30,												For the Nine Months Ended September 30,										For the Three Months Ended September 30,												For the Nine Months Ended September 30,
	2019						2018						2019						2018				2020						2019						2020				2019
(Millions of Dollars, Except Per Share Amounts)	Amount			Per Share			Amount			Per Share			Amount			Per Share			Amount		Per Share		Amount			Per Share			Amount			Per Share			Amount		Per Share		Amount			Per Share
Net Income - Regulated Companies (GAAP)	$	305.2		$	0.95		$	288.3		$	0.91		$	645.0		$	2.01		$	785.4	$	2.47	$	340.2		$	0.99		$	305.2		$	0.95		$	941.8	$	2.79	$	645.0		$	2.01

Electric Distribution	$	197.3		$	0.61		$	173.8		$	0.55		$	422.7		$	1.32		$	379.3	$	1.19	$	205.5		$	0.60		$	197.3		$	0.61		$	450.6	$	1.33	$	422.7		$	1.32
Electric Transmission, excluding Northern Pass Transmission impairment (Non-GAAP)	107.5			0.33			109.5			0.34			342.8			1.07			329.6		1.04		125.6			0.36			107.5			0.33			381.8		1.13		342.8			1.07
Natural Gas Distribution	(17.1		)	(0.05		)	(12.6		)	(0.04		)	57.6			0.18			50.2		0.16		(14.0		)	(0.04		)	(17.1		)	(0.05		)	73.8		0.22		57.6			0.18
Water Distribution	17.5			0.06			17.6			0.06			26.3			0.08			26.3		0.08		23.1			0.07			17.5			0.06			35.6		0.11		26.3			0.08
Net Income - Regulated Companies (Non-GAAP)	$	305.2		$	0.95		$	288.3		$	0.91		$	849.4		$	2.65		$	785.4	$	2.47	$	340.2		$	0.99		$	305.2		$	0.95		$	941.8	$	2.79	$	849.4		$	2.65
Impairment of Northern Pass Transmission (after-tax)	—			—			—			—			(204.4		)	(0.64		)	—		—		—			—			—			—			—		—		(204.4		)	(0.64		)
Net Income - Regulated Companies (GAAP)	$	305.2		$	0.95		$	288.3		$	0.91		$	645.0		$	2.01		$	785.4	$	2.47	$	340.2		$	0.99		$	305.2		$	0.95		$	941.8	$	2.79	$	645.0		$	2.01

Our electric distribution segment earnings increased ~~$23.5~~$8.2 million in the third quarter of ~~2019,~~2020, as compared to the third quarter of ~~2018,~~2019, due primarily to ~~CL&P~~ base distribution rate increases at CL&P effective May 1, ~~2019~~2020 and ~~May 1, 2018, an~~at NSTAR Electric ~~base distribution rate increase~~ effective January 1, ~~2019, the base distribution rate increase at PSNH effective July 1, 2019, lower non-tracked operations~~2020, and maintenance expense and the property tax settlement at PSNH, partially offset by the absence in 2019 of a 2018 benefit at PSNH relating to carrying charges on storm costs, lower non-service income from our benefit plans and higher depreciation expense.

Our electric distribution segment earnings increased $43.4 million in the first nine months of 2019, as compared to the first nine months of 2018, due primarily to the CL&P, NSTAR Electric and PSNH base distribution rate increases, and, effective July 1, 2018, higher earnings from CL&P's capital tracker mechanism due to increased electric system improvements. The earnings increase was partially offset by ~~the absence in 2019 of a 2018 benefit at PSNH relating to carrying charges on storm costs,~~higher operations and maintenance expense, higher property and other tax expense, and higher depreciation ~~expense, lower non-service income from our benefit plans, and the absence in 2019 of generation earnings at PSNH due to the sale of its generation assets in 2018.~~expense.

Our electric ~~transmission~~distribution segment earnings ~~decreased $2~~increased $27.9 million in the ~~third quarter~~first nine months of ~~2019,~~2020, as compared to the ~~third quarter~~first nine months of ~~2018,~~2019, due primarily to base distribution rate increases at CL&P effective May 1, 2020 and May 1, 2019, at PSNH effective July 1, 2019 and at NSTAR Electric effective January 1, 2020, and higher earnings from CL&P's capital tracker mechanism due to increased electric system improvements. The earnings increase was partially offset by higher operations and maintenance expense, higher depreciation expense, higher interest expense, higher property and other tax expense, and the absence of the ~~NPT AFUDC income related to equity.~~first quarter 2019 recognition of carrying charges on PSNH's 2013 through 2016 storm costs approved for recovery.

Our electric transmission segment earnings ~~decreased $191.2~~increased $18.1 million in the third quarter of 2020, as compared to the third quarter of 2019, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure.

Our electric transmission segment earnings increased $243.4 million in the first nine months of ~~2019,~~2020, as compared to the first nine months of ~~2018,~~2019, due primarily to the absence in 2020 of the second quarter 2019 impairment of NPT, which resulted in an after-tax charge of $204.4 million, or $0.64 per ~~share in the second quarter of 2019.~~share. Excluding the NPT impairment charge, earnings increased ~~$13.2~~$39.0 million in the first nine months of ~~2019,~~2020, as compared to the first nine months of ~~2018,~~2019, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure ~~partially offset by~~and a ~~lower~~higher benefit from the annual billing and cost reconciliation filing with FERC. ~~For further information on the impairment of NPT, see "Other Matters - Impairment of Northern Pass Transmission" in this~~ ~~Management's Discussion and Analysis of Financial Condition and Results of Operations~~.

Our natural gas distribution segment ~~earnings~~had a decreased ~~$4.5~~loss of $3.1 million in the third quarter of ~~2019,~~2020, as compared to the third quarter of ~~2018,~~2019, due primarily to lower revenues due to the seasonality of the decoupled rate structure arising from the Yankee Gas base distribution rate case that provides lower earnings in non-heating months (and greater earnings in the winter heating months). In addition, our earnings decreased due to higher operations and maintenance expense, higher property tax expense and depreciation expense, partially offset by higher earnings from capital tracker mechanisms due to continued investments in natural gas ~~infrastructure.~~infrastructure, a base distribution rate increase at Yankee Gas effective January 1, 2020 and lower interest expense, partially offset by higher depreciation expense and higher property tax expense.

Our natural gas distribution segment earnings increased ~~$7.4~~$16.2 million in the first nine months of ~~2019,~~2020, as compared to the first nine months of ~~2018,~~2019, due primarily to ~~the impact of the Yankee Gas~~a base distribution rate increase at Yankee Gas effective ~~November 15, 2018 and~~January 1, 2020, higher earnings from capital tracker mechanisms due to continued investments in natural gas ~~infrastructure. The earnings increase was~~infrastructure and lower interest expense, partially offset by higher depreciation expense, higher operations and maintenance expense, and higher property ~~and other~~ tax ~~expense, and depreciation~~ expense.

Our water distribution segment ~~had~~ earnings ~~of $17.5~~increased $5.6 million and $9.3 million in the third quarter and first nine months of ~~2019~~2020, respectively, as compared to the third quarter and ~~$26.3 million in the~~ first nine months of 2019, ~~compared with $17.6~~due primarily to an after-tax gain of $3.5 million on the sale of the water system and treatment plant of the Hingham, Massachusetts business, a gain on the sale of land, and lower interest expense. The increase in ~~the third quarter of 2018 and $26.3 million in~~earnings for the first nine months ~~of 2018. Our water distribution business is seasonal, with lower earnings occurring during the winter months and~~was also due to higher ~~earnings occurring during the summer months.~~revenues from Connecticut's capital tracker mechanism due to increased infrastructure improvements.

Eversource Parent and Other Companies: Eversource parent and other ~~companies had~~companies' earnings ~~of $13.7~~decreased $7.6 million and $22.6 million in the third quarter ~~of 2019~~ and ~~$14.0 million in the~~ first nine months of ~~2019, compared with $1.1 million in the third quarter of 2018 and $16.3 million in the first nine months of 2018. The increase in earnings in the third quarter of 2019,~~2020, respectively, as compared to the third quarter and first nine months of ~~2018, was~~2019, due primarily to the ~~absence~~costs of the CMA asset acquisition of $5.3 million and $12.8 million in ~~2019 of~~ the third quarter ~~2018 impairment~~and first nine months of ~~our investment in the Access Northeast project, partially offset by the absence in 2019 of income tax benefits recognized in 2018, and higher interest expense~~. 2020, respectively. The decrease in earnings infor the first nine months of ~~2019,~~2020, as compared to the first nine months of ~~2018,~~2019, was also due ~~primarily~~ to ~~the absence~~lower unrealized gains associated with our equity method investment in ~~2019 of income tax benefits recognized in 2018, and higher interest expense,~~a renewable energy fund, partially offset by ~~the absence of the third quarter 2018 impairment of our investment in the Access Northeast project, and~~ a higher return at Eversource Service as a result of increased investments in property, plant and ~~equipment.~~

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

Fluctuations in retail electric sales volumes at PSNH impact earnings ("Traditional" in the table below). For CL&P, NSTAR Electric, Yankee Gas, and NSTAR Gas, fluctuations in retail sales volumes do not impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms ("Decoupled" in the table below). These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues. Fluctuations in water sales volumes largely do not impact earnings as our Connecticut water distribution business is also decoupled.

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

Electric Firm Natural Gas Water
Sales Volumes (GWh) Percentage
Decrease Sales Volumes (MMcf) Percentage
Increase Sales Volumes (MG) Percentage
Decrease
Three Months Ended September 30: 2019
2018 ⁽¹⁾
2019
2018 ⁽²⁾
2019 2018
Traditional 2,078
2,206
(5.8 )% —
—
— % 695
732
(5.1 )%
Decoupled and Special Contracts ⁽³⁾
12,261
13,110
(6.5 )% 11,557
11,342
1.9 % 6,961
7,118
(2.2 )%
Total Sales Volumes 14,339
15,316
(6.4 )% 11,557
11,342
1.9 % 7,656
7,850
(2.5 )%

Nine Months Ended September 30:
Traditional 5,803
5,981
(3.0 )% —
—
— % 1,604
1,684
(4.8 )%
Decoupled and Special Contracts ⁽³⁾
33,298
34,690
(4.0 )% 74,915
73,325
2.2 % 16,173
16,491
(1.9 )%
Total Sales Volumes 39,101
40,671
(3.9 )% 74,915
73,325
2.2 % 17,777
18,175
(2.2 )%

⁽¹⁾ Effective February 1, 2018, NSTAR Electric operated entirely under a decoupled rate structure. The 2018 sales volumes for NSTAR Electric have been recast to present January 2018 as decoupled to conform to the current year presentation.

⁽²⁾ Effective November 15, 2018, Yankee Gas operated under a decoupled rate structure. The 2018 sales volumes for Yankee Gas have been recast to present 2018 as decoupled to conform to the current year presentation.

⁽³⁾ Special contracts are unique to Yankee Gas natural gas distribution customers who take service under such an arrangement and generally specify the amount of distribution revenue to be paid to Yankee Gas regardless of the customers' usage.lower interest expense.

Liquidity

Cash and Cash Equivalents totaled ~~$22.7~~$730.0 million as of September 30, ~~2019, compared with $108.1~~2020 and were used to acquire the CMA assets on October 9, 2020. Cash totaled $15.4 million as of December 31, ~~2018.~~2019.

The amount of borrowings outstanding and available under the commercial paper programs were as follows:


	Borrowings Outstanding as of				Available Borrowing Capacity as of				Weighted-Average Interest Rate as of					Borrowings Outstanding as of							Available Borrowing Capacity as of						Weighted-Average Interest Rate as of
	September 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018		September 30, 2019			December 31, 2018		September 30, 2020			December 31, 2019				September 30, 2020			December 31, 2019			September 30, 2020			December 31, 2019
(Millions of Dollars)	September 30, 2019				September 30, 2019				September 30, 2019			December 31, 2018		September 30, 2020			December 31, 2019				September 30, 2020			December 31, 2019			September 30, 2020			December 31, 2019
Eversource Parent Commercial Paper Program	$	684.5	December 31, 2018	$	631.5	$	December 31, 2018	765.5			$	818.5			2.25	%	2.77	%	$	—		$	1,224.9		$	1,450.0			$	225.1		—	%	1.98	%
NSTAR Electric Commercial Paper Program	28.0		278.5		622.0		371.5		1.98	%		2.50	%	60.5			10.5				589.5			639.5			0.10	%		1.63	%

There were no borrowings outstanding on ~~either~~ the ~~Eversource parent or NSTAR Electric~~ revolving credit facilities as of September 30, ~~2019~~2020 or December 31, ~~2018.~~2019.

On May 15, 2020, CL&P and PSNH entered into uncommitted line of credit agreements, which will expire by May 14, 2021. The CL&P agreements total $450 million and the PSNH agreements total $300 million. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of September 30, 2020.

Long-Term Debt Issuance Authorization: On January 27, 2020, the DPU approved NSTAR Gas' request for authorization to issue up to $270 million in long-term debt through December 31, 2021. On July 31, 2020, the NHPUC approved PSNH's request for authorization to issue up to $200 million in long-term debt through December 31, 2020.

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



(Millions of Dollars)	Issuance/(Repayment)			Issue Date or Repayment Date	Maturity Date	Use of Proceeds for Issuance/ Repayment Information
NSTAR Electric:
3.95% 2020 Debentures	$	400.0		March 2020	April 2030	Refinanced investments in eligible green expenditures, which were previously financed in 2018 and 2019
5.10% Series E Senior Notes	(95.0		)	March 2020	March 2020	Paid at maturity
PSNH:
2.40% Series U First Mortgage Bonds	150.0			August 2020	September 2050	Refinanced short-term borrowings, funded capital expenditures and working capital
Other:
Eversource Parent 3.45% Series P Senior Notes	350.0			January 2020	January 2050	Paid short-term borrowings
Eversource Parent 3.45% Series P Senior Notes ⁽¹⁾	300.0			August 2020	January 2050	⁽²⁾
Eversource Parent 0.80% Series Q Senior Notes	300.0			August 2020	August 2025	⁽²⁾
Eversource Parent 1.65% Series R Senior Notes	600.0			August 2020	August 2030	⁽²⁾
NSTAR Gas 4.46% Series N First Mortgage Bonds	(125.0		)	January 2020	January 2020	Paid at maturity
NSTAR Gas 2.33% Series R First Mortgage Bonds	75.0			May 2020	May 2025	Refinanced existing indebtedness, funded capital expenditures and for general corporate purposes
NSTAR Gas 3.15% Series S First Mortgage Bonds	115.0			May 2020	May 2050	Refinanced existing indebtedness, funded capital expenditures and for general corporate purposes
Yankee Gas 4.87% Series K First Mortgage Bonds	(50.0		)	April 2020	April 2020	Paid at maturity
Yankee Gas 2.90% Series R First Mortgage Bonds	70.0			September 2020	September 2050	Refinanced existing indebtedness, funded capital expenditures and for general corporate purposes
Aquarion Water Company of Massachusetts, Inc. and Aquarion Water Capital of Massachusetts, Inc. various term loans and general mortgage bonds	(32.2		)	July 2020	Various	Redeemed long-term debt in conjunction with the sale of assets to the Town of Hingham, Massachusetts


⁽¹⁾	These ~~bonds~~senior notes are part of the same series issued by ~~CL&P~~Eversource parent in ~~March 2018.~~January 2020. The aggregate outstanding principal amount of these ~~bonds~~senior notes is now ~~$800~~$650 million.


⁽²⁾	~~These bonds are part~~A portion of the ~~same series issued by CL&P in March 2017. The aggregate outstanding principal amount of~~proceeds from these ~~bonds is now $500 million.~~Eversource parent issuances were used to acquire the CMA assets, with the remaining used to refinance short-term borrowings.

~~Long-Term Debt Issuance Authorization:~~ On April 26, 2019, the NHPUC approved PSNH’s request for authorization to issue up to $300 million in long-term debt through December 31, 2019. On August 14, 2019, PURA approved CL&P’s request for authorization to issue up to $675 million in long-term debt through December 31, 2022.

~~Eversource does not expect to issue additional public long-term debt in 2019.~~

Rate Reduction Bonds: PSNH's RRB payments consist of principal and interest and are paid ~~semi-annually, beginning on February 1, 2019.~~semi-annually. PSNH paid $43.2 million of RRB principal payments and $20.2 million of interest payments in the first nine months of 2020 and paid $52.3 million of RRB principal payments and $26.8 million of interest payments in the first nine months of 2019.

Common Share ~~Issuance~~Issuances and 2019 Forward Sale Agreement:On June ~~4, 2019,~~15, 2020, Eversource completed an equity offering of ~~17,940,000~~6,000,000 common shares, consisting of 5,980,000 common shares issued directly by us and 11,960,000 common shares issuable pursuant to a forward sale agreement with an investment bank. The issuance of 5,980,000 common shares resultedresulting in proceeds of ~~$426.9~~$509.2 million, net of issuance ~~costs, and was reflected in shareholders’ equity and as~~costs. On March 23, 2020, Eversource physically settled a ~~financing activity on the statement~~portion of ~~cash flows.~~

Under the forward sale agreement, a total of 11,960,000 common shares were borrowed from third parties and sold by the underwriters. The forward sale agreement allows Eversource, at its election and prior to May 29, 2020, to physically settle the forward sale agreement by ~~issuing~~delivering 1,500,000 common shares in exchange for net proceeds atof $105.7 million. Subsequently, on March 26, 2020, Eversource physically settled the ~~then-applicable forward sale price specified by the agreement (initially, $71.48 per share) or, alternatively, to settle the forward sale agreement in whole or in part through the delivery or receipt~~remaining portion of shares or cash. The forward sale price is subject to adjustment daily based on a floating interest rate factor and will decrease in respect of certain fixed amounts specified in the agreement, such as dividends.

~~Eversource’s intent is to physically settle~~ the forward sale agreement by issuing common shares. As of September 30, 2019, if Eversource had elected to net settle the forward sale agreement, Eversource would have been required to pay $169.7 million under a cash settlement or would have been required to deliver 1,985,105delivering 4,460,000 common shares ~~under a~~in exchange for net proceeds of $314.1 million. The March and June 2020 common share ~~settlement.~~

~~Issuances~~issuances resulted in total proceeds of ~~shares under the forward sale agreement are classified~~$929.0 million, net of issuance costs, and were reflected in shareholders' equity and as equity transactions. Accordingly, no amounts relating to the forward sale agreement have or will be recorded in the financial statements until settlements take place. Prior to any settlements, the only impact to the financial statements is the inclusion of incremental shares within the calculation of diluted EPS using the treasury stock method. See Note 15, "Earnings Per Share," for informationfinancing activities on the ~~forward sale agreement’s impact on the calculation~~statement of ~~diluted EPS.~~

~~Eversource intends to use~~cash flows. A portion of the net proceeds ~~received upon~~were used to acquire the direct issuance of common shares and the net proceeds expected to be received upon settlement of the forward sale agreement to repay short-term debt under the commercial paper program, to fund capital spending to enhance reliability and fund clean energy initiatives, and for general corporate purposes.CMA assets.

Cash Flows: Cash flows provided by operating activities totaled $1.50 billion in the first nine months of 2020, compared with $1.49 billion in the first nine months of ~~2019, compared with $1.41 billion in the first nine months of 2018. The increase in operating~~2019. Operating cash flows ~~was due primarily to~~were favorably impacted by the timing of cash payments made on our accounts payable and other working capital items, and a decrease of $12.4 million in ~~2019 of approximately $212 million of major storm restoration cost payments,~~Pension and PBOP contributions made in 2020, as compared to 2019. These favorable impacts were partially offset by the timing of cash collections on our accounts receivable, ~~and a $68.5 million decrease in pension and PBOP~~ cash ~~contributions made in 2019, as compared to the same period in 2018. Also contributing to the increase were $17.4 million of lower income tax~~ payments made in ~~2019, as compared~~2020 for storm restoration costs of approximately $56 million related to ~~2018,~~Tropical Storm Isaias, the timing of collections for regulatory tracking mechanisms primarily related to transmission costs and the impact of the CL&P temporary rate suspension, the absence of $68.8 million in DOE Phase IV proceeds received by CYAPC and YAEC in the second quarter of ~~2019. Partially offsetting these favorable impacts were the timing of collections for regulatory tracking mechanisms,~~2019, and the timing of ~~accounts payable cash payments~~fuel, material, supplies and ~~other working capital items.~~REC inventories.

On September ~~9, 2019,~~2, 2020, our Board of Trustees approved a common share dividend payment of ~~$0.535~~$0.5675 per share, which was paid on September 30, ~~2019~~2020 to shareholders of record as of September ~~20, 2019.~~17, 2020. In the first nine months of 2020, we paid cash dividends of $555.7 million and issued non-cash dividends of $17.2 million in the form of treasury shares, totaling dividends of $572.9 million. In the first nine months of 2019, we paid cash dividends of $495.6 million ~~compared with $480.1~~and issued non-cash dividends of $17.2 million ~~paid~~ in the ~~first nine months~~form of ~~2018.~~treasury shares, totaling dividends of $512.8 million.

~~In the first nine months of 2019, CL&P, NSTAR Electric and PSNH paid $341.8 million, $181.8 million, and $252.0 million, respectively, in common stock dividends to~~ Eversource ~~parent.~~

~~Beginning in 2019, Eversource began issuing~~issues treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan.

In the first nine months of 2020, CL&P, NSTAR Electric and PSNH paid $69.5 million, $196.5 million, and $22.3 million, respectively, in common stock dividends to Eversource parent.

Investments in Property, Plant and Equipment on the statements of cash flows do not include amounts incurred on capital projects but not yet paid, cost of removal, AFUDC related to equity funds, and the capitalized and deferred portions of pension and PBOP expense. In the first nine months of ~~2019,~~2020, investments for Eversource, CL&P, NSTAR Electric, and PSNH were ~~$2.13~~$2.10 billion, ~~$699.3~~$609.7 million, ~~$636.2~~$655.0 million, and ~~$209.0~~$248.9 million, respectively.

We expect the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with our existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.

~~Credit Ratings:~~ ~~On July 25, 2019, S&P downgraded the ratings on Eversource and all of its subsidiaries and revised the outlooks from negative to stable.~~

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



	~~Moody's~~		~~S&P~~		~~Fitch~~
	~~Current~~	~~Outlook~~	~~Current~~	~~Outlook~~	~~Current~~	~~Outlook~~
~~Eversource Parent~~	~~Baa1~~	~~Stable~~	A-	~~Stable~~	~~BBB+~~	~~Stable~~
~~CL&P~~	A3	~~Stable~~	A	~~Stable~~	A-	~~Stable~~
~~NSTAR Electric~~	A1	~~Stable~~	A	~~Stable~~	A	~~Stable~~
~~PSNH~~	A3	~~Stable~~	A	~~Stable~~	A-	~~Stable~~

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



	~~Moody's~~		~~S&P~~		~~Fitch~~
	~~Current~~	~~Outlook~~	~~Current~~	~~Outlook~~	~~Current~~	~~Outlook~~
~~Eversource Parent~~	~~Baa1~~	~~Stable~~	~~BBB+~~	~~Stable~~	~~BBB+~~	~~Stable~~
~~CL&P~~	A1	~~Stable~~	A+	~~Stable~~	A+	~~Stable~~
~~NSTAR Electric~~	A1	~~Stable~~	A	~~Stable~~	A+	~~Stable~~
~~PSNH~~	A1	~~Stable~~	A+	~~Stable~~	A+	~~Stable~~

Business Development and Capital Expenditures

Our consolidated capital expenditures, including amounts incurred but not paid, cost of removal, AFUDC, and the capitalized and deferred portions of pension and PBOP expense (all of which are non-cash factors), totaled $2.19 billion in the first nine months of 2020, compared to $2.18 billion in the first nine months of ~~2019, compared to $1.96 billion in the first nine months of 2018.~~2019. These amounts included ~~$158.8~~$178.3 million and ~~$113.9~~$158.8 million in the first nine months of ~~2019~~2020 and ~~2018,~~2019, respectively, related to information technology and facilities upgrades and enhancements, primarily at Eversource Service and The Rocky River Realty Company.

Electric Transmission Business: Our consolidated electric transmission business capital expenditures ~~decreased~~increased by ~~$35.0~~$15.8 million in the first nine months of ~~2019,~~2020, as compared to the first nine months of ~~2018.~~2019. A summary of electric transmission capital expenditures by company is as follows:


	For the Nine Months Ended September 30,				For the Nine Months Ended September 30,
(Millions of Dollars)	2019		2018		2020		2019
CL&P	$	333.6	$	346.7	$	296.4	$	333.6
NSTAR Electric	237.3		210.8		253.6		237.3
PSNH	108.4		142.1		154.8		108.4
NPT	9.7		24.4		—		9.7
Total Electric Transmission Segment	$	689.0	$	724.0	$	704.8	$	689.0

Eastern Massachusetts Transmission Projects: These projects consist of a portfolio of electric transmission upgrades in southern New Hampshire, northern Massachusetts and continuing into the greater Boston metropolitan area, of which 28 upgrades are in Eversource's service territory (two in New Hampshire and 26 in Massachusetts). The two New Hampshire upgrades, including the Merrimack Valley Reliability Project, have been placed in service, and 1721 Massachusetts upgrades have been placed in service. ~~The majority~~On December 17, 2019, the Massachusetts Siting Board issued a favorable decision on the Sudbury-Hudson Reliability Project, the last project requiring such approval. On January 17, 2020, the Town of Sudbury and Protect Sudbury, a community group, appealed the decision to the Massachusetts Supreme Judicial Court (SJC) and oral arguments are scheduled for March 2021. Additionally, on September 22, 2020, the SJC affirmed the Massachusetts Land Court’s earlier decision to dismiss the Town of Sudbury’s separate complaint that claimed the Massachusetts Bay Transportation Authority did not have the authority to lease property to Eversource, a private entity. The remaining upgrades are under construction and are expected to be placed in service in ~~2021.~~2022. We estimate our portion of the investment will be approximately ~~$700~~$750 million, of which ~~$414~~$497.3 million has been spent and capitalized through September 30, ~~2019.~~2020.

~~GHCC~~Southeastern Massachusetts Transmission Projects: ~~The Greater Hartford Central Connecticut ("GHCC") Solution~~These projects consist of a portfolio of electric transmission and substation upgrades in southeastern Massachusetts, including Cape Cod, required to reinforce the Southeastern Massachusetts transmission system and bring the system into compliance with applicable national and regional reliability standards. ISO-NE reassessed the need for projects that had yet to be constructed and reconfirmed the need for the majority of the originally identified reinforcements in July 2020. Twelve upgrades in Eversource's service territory were reconfirmed, and a single upgrade was deemed to no longer be required. Of the twelve upgrades, four require siting approvals from the Massachusetts regulatory agencies, of which three are before the agencies and one, a joint project with National Grid, has yet to be filed. Three substation projects will be permitted locally, three projects are under construction and two projects have been placed in-service. We estimate our portion of the investment will be approximately $175 million, of which $27 million has been spent and capitalized through September 30, 2020.

Hartford-Area Transmission Projects: This portfolio of projects consists of 27 projects in the Hartford, Connecticut area with an expected ~~investment~~total cost of approximately ~~$350~~$302 million. As of September 30, ~~2019, 24~~2020, all projects have been placed in service and ~~three projects are in active construction and are expected to be placed in service through mid-2020. As of September 30, 2019,~~ CL&P ~~had~~has spent and capitalized ~~$265.7~~$298.5 million in costs associated with ~~GHCC.~~

~~Seacoast Reliability Project~~:these projects. The ~~Seacoast Reliability Project consists of a 13-mile, 115kV transmission line within several New Hampshire communities, using a combination of overhead, underground and underwater line designs~~remaining project costs are expected to ~~help meet the growing demand for electricity~~be spent in the Seacoast region. On December 10, 2018, the NHSEC indicated its unanimous approval of the project, and subsequently issued its written decision on January 31, 2019. On April 11, 2019, the NHSEC issued its written decision denying motions for rehearing submitted by three entities that intervened in the proceeding. On May 13, 2019, two appeals of the NHSEC's approval orders were filed with the New Hampshire Supreme Court. While the court has not yet determined whether it will hear those appeals, it denied a motion for a stay of construction on August 22, 2019. On October 14, 2019, the U.S. District Court denied a motion for a preliminary injunction to stop construction of the project in wetlands until after an appeal of the U.S. Army Corps of Engineers permit is deliberated. This project is under construction and is scheduled to be completed in the secondfourth quarter of 2020. We now estimate the investment in this project to be approximately $125 million, of which PSNH had spent and capitalized $51.7 million in costs through September 30, 2019. The increase of approximately $40 million was due primarily to revised schedules associated with the extensive siting and permitting processes and mandated permit conditions included with the approvals.

All project costs are anticipated to be fully recoverable through transmission rates.

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


	For the Nine Months Ended September 30,														For the Nine Months Ended September 30,
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		Total Electric		Natural Gas		Water		Total		CL&P		NSTAR Electric		PSNH		Total Electric		Natural Gas		Water		Total
2020
Basic Business															$	149.4	$	146.5	$	38.9	$	334.8	$	59.7	$	7.6	$	402.1
Aging Infrastructure															133.2		178.8		58.7		370.7		268.0		82.5		721.2
Load Growth and Other															55.3		69.2		14.6		139.1		39.2		0.6		178.9
Total Distribution															337.9		394.5		112.2		844.6		366.9		90.7		1,302.2
Solar															—		1.1		—		1.1		—		—		1.1
Total															$	337.9	$	395.6	$	112.2	$	845.7	$	366.9	$	90.7	$	1,303.3
2019
Basic Business	$	189.4	$	204.8	$	29.4	$	423.6	$	48.7	$	9.8	$	482.1	$	189.4	$	204.8	$	29.4	$	423.6	$	48.7	$	9.8	$	482.1
Aging Infrastructure	171.2		143.2		74.7		389.1		225.2		65.4		679.7		171.2		143.2		74.7		389.1		225.2		65.4		679.7
Load Growth and Other	46.0		55.3		11.1		112.4		51.5		1.2		165.1		46.0		55.3		11.1		112.4		51.5		1.2		165.1
Total Distribution	406.6		403.3		115.2		925.1		325.4		76.4		1,326.9		406.6		403.3		115.2		925.1		325.4		76.4		1,326.9
Solar	—		6.6		—		6.6		—		—		6.6		—		6.6		—		6.6		—		—		6.6
Total	$	406.6	$	409.9	$	115.2	$	931.7	$	325.4	$	76.4	$	1,333.5	$	406.6	$	409.9	$	115.2	$	931.7	$	325.4	$	76.4	$	1,333.5
2018
Basic Business	$	199.5	$	144.6	$	57.4	$	401.5	$	52.7	$	10.9	$	465.1
Aging Infrastructure	100.7		79.7		61.6		242.0		166.3		51.4		459.7
Load Growth and Other	59.5		39.3		9.1		107.9		38.2		1.8		147.9
Total Distribution	359.7		263.6		128.1		751.4		257.2		64.1		1,072.7
Solar and Generation	—		48.1		0.9		49.0		—		—		49.0
Total	$	359.7	$	311.7	$	129.0	$	800.4	$	257.2	$	64.1	$	1,121.7

For the electric distribution business, basic business includes the purchase of meters, tools, vehicles, information technology, transformer replacements, equipment facilities, and the relocation of plant. Aging infrastructure relates to reliability and the replacement of overhead lines, plant substations, underground cable replacement, and equipment failures. Load growth and other includes requests for new business and capacity additions on distribution lines and substation additions and expansions.

For the natural gas distribution business, basic business addresses daily operational needs including meters, pipe relocations due to public works projects, vehicles, and tools. Aging infrastructure projects seek to improve the reliability of the system through enhancements related to cast iron and bare steel replacement of main and services, corrosion mediation, and station upgrades. Load growth and other reflects growth in existing service territories including new developments, installation of services, and expansion.

For the water distribution business, basic business addresses daily operational needs including periodic meter replacement, water main relocation, facility maintenance, and tools. Aging infrastructure relates to reliability and the replacement of water mains, regulators, storage tanks, pumping stations, wellfields, reservoirs, and treatment facilities. Load growth and other reflects growth in our service territory, including improvements toof acquisitions, installation of new services, and interconnections of systems.

Acquisition of Assets of Columbia Gas of Massachusetts: On October 9, 2020, Eversource acquired certain assets that comprised NiSource’s local natural gas distribution business in Massachusetts, which was previously doing business as CMA, pursuant to an asset purchase agreement (the Agreement) entered into on February 26, 2020 between Eversource and NiSource Inc. The cash purchase price was $1.1 billion plus a target working capital amount, which is subject to adjustment to reflect actual working capital as of the closing date. Eversource financed the asset acquisition through a combination of debt and equity issuances in a ratio that was consistent with our consolidated capital structure. The natural gas distribution assets acquired from CMA were assigned to Eversource Gas Company of Massachusetts, an indirect wholly-owned subsidiary of Eversource formed in 2020. The LNG assets acquired from CMA were assigned to Hopkinton LNG Corp. Eversource Gas Company of Massachusetts distributes natural gas to approximately 330,000 residential, commercial and industrial customers with over 5,000 miles of natural gas distribution pipeline across more than 60 communities in Massachusetts, adding to the approximately 300,000 natural gas customers that Eversource already serves in Massachusetts.

On October 7, 2020, the DPU approved a rate settlement agreement with Eversource, Eversource Gas Company of Massachusetts, NiSource, Bay State, the Massachusetts Attorney General's Office, the DOER and the Low-Income Weatherization and Fuel Assistance Program Network, which requested approval of the February 26, 2020 asset purchase agreement between Eversource and NiSource, as well as a rate stabilization plan, among other items. The settlement agreement included an authorized regulatory ROE of 9.70 percent as of January 1, 2021, a 53.25 percent equity component of its capital structure, and established rate base equal to $995 million as of the closing on October 9, 2020.

The approved rate stabilization plan includes base distribution rate increases of $13 million on November 1, 2021 and $10 million on November 1, 2022. The settlement agreement includes two rate base resets during an eight-year rate plan, occurring on November 1, 2024 and November 1, 2027. The two rate base resets adjust distribution rates to account for capital additions (including the roll-in of GSEP capital additions), depreciation expense, property taxes, and return on rate base for capital additions placed into service through December 31, 2023, for the first rate base reset occurring on November 1, 2024, and through December 31, 2026, for the second rate base reset occurring on November 1, 2027. Notwithstanding the two distribution rate increases and the two rate base reset provisions, Eversource Gas Company of Massachusetts is not able to file for an increase or redesign of distribution base rates effective prior to November 1, 2028.

The settlement agreement also permits Eversource Gas Company of Massachusetts to seek recovery of both transaction and integration costs as a result of the asset acquisition after December 31, 2026, subject to DPU review and approval, and subject to certain conditions, such as demonstrating savings resulting from the acquisition.

Offshore Wind Business: Our offshore wind business includes ownership interests in North East Offshore and Bay State Wind, which together hold ~~power purchase agreements (PPAs)~~PPAs and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind ~~projects.~~projects, as well as offshore leases issued by BOEM. Our offshore wind projects are being developed inand constructed through a joint and equal partnership with Ørsted. This ~~business~~partnership also participates in new procurement opportunities ~~for solicitations~~ for offshore wind energy in the Northeast U.S. On July 21, 2020, New York's second offshore wind RFP for up to 2,500 MW was issued, and on October 20, 2020, we submitted proposals for our Sunrise Wind 2 project in response to the RFP.

~~On February 8, 2019,~~ Eversource and Ørsted entered into an equal partnership to acquire key offshore wind assets in the Northeast, where Eversource owns 50 percent of these assets. Eversource's initial payment and contribution under the terms of the partnership agreements totaled approximately $225 million forhas a 50 percent ownership interest in North East Offshore, which holds the Revolution Wind and South Fork Wind projects, as well as a 257 square-mile ocean lease off the coasts of Massachusetts and Rhode Island. Eversource also has a 50 percent ownership interest in Bay State Wind, which holds the Sunrise Wind project. Bay State Wind's separate 300-square-mile ocean lease ~~area~~ is located approximately 25 miles south of the coast of Massachusetts ~~on a separate 300-square-mile ocean lease~~ adjacent to the North East Offshore ~~area and has the ultimate potential to generate at least 2,000 MW of clean, renewable energy. Together,~~area. In aggregate, the Bay State Wind and the North East Offshore ocean lease sites jointly-owned by Eversource and Ørsted could eventually develop at least 4,000 MW of clean, renewable offshore wind energy. ~~In the third quarter of 2019, Eversource made additional capital contributions of $133.6 million.~~ As of September 30, ~~2019,~~2020, Eversource's total equity investment balance in its offshore wind business was ~~$637.2~~$679.4 million.

We are preparing our final project designs and advancing the appropriate federal, state and local siting and permitting processes along with our offshore wind partner, Ørsted, all of which is competitively sensitive. We currently expect to make investments in our offshore wind business of approximately $200 million to $400 million during 2020, subject to advancing our final project designs and federal, state and local permitting processes.

The following table provides a summary of the Eversource and Ørsted major projects with announced contracts:

Wind Project

State Servicing

Size (MW)

Term (Years)

Price per MWh ⁽¹⁾

Projected In-Service Date

State Servicing

Size (MW)

Term (Years)

Price per MWh

Pricing Terms

Contract Status

Revolution Wind

Rhode Island

400

$98.43

Late 2023

Rhode Island

400

$98.43

Fixed price contract; no price escalation

Approved

Revolution Wind

Connecticut

304

⁽²⁾

Late 2023

Connecticut

304

⁽¹⁾

Fixed price contracts; no price escalation

Approved

South Fork Wind

New York (LIPA)

$160.33

End of 2022

New York (LIPA)

$160.33

2 percent average price escalation

Approved

South Fork Wind

New York (LIPA)

$86.25 ⁽²⁾

End of 2022

New York (LIPA)

$86.25

2 percent average price escalation

⁽³⁾

Sunrise Wind

New York (NYSERDA)

880

$110.37 ⁽³⁾

2024

New York (NYSERDA)

880

$110.37 ⁽²⁾

Fixed price contract; no price escalation

Approved


⁽¹⁾	The pricing for the Revolution Wind ~~and Sunrise Wind are fixed price~~ contracts ~~with no price escalation. South Fork Wind includes a 2 percent average price escalation over the contract term.~~in Connecticut has not been publicly disclosed.


⁽²⁾	~~Revolution~~Index Offshore Wind ~~104 MW PPAs (for which pricing has not yet been publicly disclosed) and South Fork Wind PPA-amendment are awaiting regulatory approval.~~Renewable Energy Certificate (OREC) strike price.


⁽³⁾	~~Index OREC strike price.~~The Long Island Power Authority (LIPA) agreed to expand the original 20-year PPA from 90 MW to 130 MW through an amendment to the original agreement. The amendment is awaiting final approval from the New York Comptroller's Office.

~~Revolution Wind, South Fork Wind,~~The in-service dates for our offshore wind projects are subject to receipt of federal, state and ~~Sunrise Wind Projects~~:local approvals necessary to construct and operate the projects. The ~~Revolution Wind project was selected under separate Connecticut~~federal permitting process is governed by BOEM, and state approvals are required from New York, Rhode Island ~~procurements based on each state's clean energy requirements.~~ and Massachusetts. Significant delays in the siting and permitting process resulting from the timeline for obtaining approval from BOEM and the state and local agencies, as well as the impact of COVID-19, could adversely impact the timing of these projects' in-service dates.

In ~~Rhode Island, a 20-year PPA for 400 MW was executed and has been approved by~~June 2020, BOEM released its Offshore Wind Cumulative Impact Analysis as part of the ~~Rhode Island Public Utilities Commission. In Connecticut, two 20-year PPAs~~Draft Supplemental Environmental Impact Statement (EIS) for a ~~total~~non-affiliated offshore wind project. The study assessed the environmental, social, and economic impacts of ~~200 MW were executed and have been approved by~~constructing 22 GW of offshore wind projects in every federal lease area along the ~~PURA, and two 20-year PPAs~~East Coast. While this analysis was performed for the purpose of completing the permitting review of a ~~total of 104 MW were executed and are currently awaiting regulatory approval.~~non-affiliated project, we anticipate that this analysis has produced a replicable methodology for completing this analysis that should reduce the timeline for completing future BOEM reviews.

The South Fork Wind project ~~was selected by~~has commenced the ~~Long Island Power Authority (LIPA)~~federal siting and permitting process with the filing of its Construction Operations Plan (COP) application with BOEM in October 2018. The first major milestone in the BOEM review process is an issuance of a Notice of Intent to complete an Environmental Impact Statement (NOI), which South Fork Wind has received. In August 2020, we received the final review schedule from BOEM regarding South Fork Wind’s COP approval. Based on this schedule and final United States Army Corps of Engineers approval, we expect to start construction on South Fork in early 2022. South Fork Wind is designated as a “Covered Project” pursuant to Title 41 of the Fixing America’s Surface Transportation Act (“FAST41”) and a ~~20-year PPA~~Major Infrastructure Project under Section 3(e) of Executive Order 13807, which provides greater federal attention on meeting the project’s permitting timelines. South Fork Wind’s FAST41 designation is due for ~~90 MW was executed~~reauthorization in 2020.

Revolution Wind and ~~approved. Subsequently, LIPA agreed~~Sunrise Wind filed their COP applications with BOEM in March 2020 and September 2020, respectively. Both projects received FAST41 designation in 2020. We are awaiting BOEM to ~~expand~~outline its timeline for completing the ~~original PPA to 130 MW through~~review of each of the Revolution Wind and Sunrise Wind COPs in an ~~amendment~~NOI.

South Fork Wind commenced the New York state siting process in 2018. On September 25, 2020, the state of New York Administrative Law Judge granted a change to the ~~original agreement. Negotiations~~start of the South Fork Wind evidentiary hearing schedule to December 2, 2020, due to continuing settlement conferences amongst the parties. Onshore and near-shore site investigation activities occurring within New York’s jurisdiction were suspended in March 2020 due to work restrictions imposed in response to the COVID-19 pandemic. The activities that were suspended included offshore site investigations, and onshore environmental and geotechnical surveys. These activities resumed in early June following the release of revised guidance from the New York State Energy Research and Development Authority (NYSERDA). We are ~~currently underway~~developing mitigation plans to ~~finalize this amendment.~~address the impacts of the approximately two-month suspension of field activities due to these COVID-19 restrictions. These mitigation plans are intended to limit the impact and risk to our project timelines.

On September 17, 2020, South Fork Wind filed a Joint Proposal in the New York State Article VII siting application. Amongst other things, the Joint Proposal included proposed mitigations to certain environmental, community and construction impacts associated with constructing electrical infrastructure. South Fork Wind was initially joined by PSEG Long Island and several citizens advocacy organizations. On October ~~23, 2019, NYSERDA~~9, 2020, the Joint Proposal was signed by the New York Departments of Public Service, Environmental Conservation, Transportation and State as well as the Office of Parks, Recreation and Historic Preservation.

On September 10, 2020, the Town of East Hampton and the East Hampton Town Trustees announced ~~the execution of a 25-year~~that they had reached an agreement with South Fork Wind to issue the ~~Sunrise~~necessary easements and other real estate rights necessary to construct the South Fork Wind project.

Based on BOEM’s confirmed permit schedule outlining when BOEM will complete its review of the South Fork Wind COP, we now expect the South Fork Wind project to ~~purchase ORECs from an 880 MW offshore wind facility. The Sunrise~~be in-service by the end of 2023.

We anticipate the principal state permitting applications for Revolution Wind ~~project is held by Bay State Wind~~ and ~~will use a combination of lease areas from Bay State Wind and North East Offshore.~~ Sunrise Wind will be ~~developed 35 miles east~~filed in Rhode Island and New York, respectively, by the end of ~~Montauk Point, Long Island.~~

~~The completion dates for these projects are~~2020. Sunrise Wind was subject to the same New York work restrictions as South Fork Wind between March 2020 and June 2020. For Sunrise Wind, these restrictions prevented progressing our site surveys in New York and within New York jurisdictional waters due to COVID-19 restrictions. These restrictions adversely impact the preparation of our federal and state permitting ~~engineering, siting~~applications. As well, we do not have a definitive timeline on when we will receive BOEM’s NOI with respect to both Revolution Wind and ~~finalizing PPAs, where applicable.~~

~~Solicitations~~Sunrise Wind. At this time, we believe that it is unlikely that the projected in-service dates of the end of 2023 and the end of 2024 for ~~Offshore~~Revolution Wind~~: Eversource~~ and ~~Ørsted participated~~Sunrise Wind, respectively, will be met. While mitigation plans are being developed, we are currently awaiting the receipt of BOEM NOIs for Revolution Wind and Sunrise Wind in ~~the following opportunities for solicitations for offshore wind based~~order to conclude on ~~each state's clean energy requirements:~~

Connecticut’s offshore wind RFP for 400 MW (and up to 2,000 MW) was issued on August 16, 2019. Eversource and Ørsted submitted several alternative bids, called Constitution Wind, on September 30, 2019. We currently expect a decision in late November 2019.

Massachusetts’ second offshore wind RFP for 400 MW to 800 MW was originally issued on May 23, 2019, and subsequently revised on August 7, 2019. Eversource and Ørsted submitted several alternative bids on August 23, 2019, none of which was selected.definitive in-service dates.

FERC Regulatory Matters

FERC ROE Complaints: Four separate complaints ~~have been~~were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively, the ~~"Complainants")~~Complainants). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive ~~("incentive cap")~~(incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.

All amounts associated with the first complaint period have been refunded. Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of September 30, 2020 and December 31, 2019. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of September 30, 2020 and December 31, 2019.

Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.

FERC ~~Notices~~Notice of ~~Inquiry:~~Inquiry on ROE: On March 21, 2019, FERC issued ~~two Notices~~a Notice of Inquiry ~~("NOI") that may affect Eversource transmission ROEs and incentives. One NOI (the "FERC ROE NOI") seeks~~(NOI) seeking comments from all stakeholders on FERC's policies for evaluating ROEs for electric public utilities, and interstate natural gas and oil pipelines. ~~The other NOI (the "FERC transmission incentives NOI") seeks comments on FERC's policies for implementing electric transmission incentives.~~ On June 26, 2019, the NETOs jointly filed comments ~~in the FERC ROE NOI,~~ supporting the methodology established in the FERC’s October 16, 2018 order with minor enhancements going forward. ~~Also~~The NETOs jointly filed reply comments in the FERC ROE NOI on July 26, 2019. On May 12, 2020, the NETOs filed supplemental comments in the NOI ROE docket. At this time, Eversource cannot predict how this proceeding will affect its transmission ROEs.

FERC Notice of Inquiry and Proposed Rulemaking on Transmission Incentives: On March 21, 2019, FERC issued an NOI seeking comments on FERC's policies for implementing electric transmission incentives. On June 26, 2019, Eversource filed comments ~~in the FERC transmission incentives NOI,~~ requesting that FERC retain policies that have been effective in encouraging new transmission investment and remain flexible enough to attract investment in new and emerging transmission technologies. ~~The NETOs jointly filed reply comments in the FERC ROE NOI on July 26, 2019.~~ Eversource filed reply comments ~~in the FERC transmission incentives NOI~~ on August 26, 2019. On March 20, 2020, FERC issued a Notice of Proposed Rulemaking (NOPR) on transmission incentives. The NOPR intends to revise FERC’s electric transmission incentive policies to reflect competing uses of transmission due to generation resource mix, technological innovation and shifts in load patterns. FERC proposes to grant transmission incentives based on measurable project economics and reliability benefits to consumers rather than its current project risks and challenges framework. On July 1, 2020, Eversource filed comments generally supporting the NOPR. At this time, Eversource cannot predict how these ~~NOIs~~proceedings will affect its ~~ROEs or~~transmission incentives.

FERC Transmission Rate Settlement: On December 28, 2015, FERC initiated a proceeding to review the NETOs' regional and local transmission formula rates due to a lack of transparency, finding that the formula rates appeared to lack sufficient details to determine how costs are derived and recovered in rates. This proceeding was set for hearing but held in abeyance to provide time for settlement judge procedures. On August 17, 2018, a signed Settlement Agreement between twenty-eight parties, including all six New England state regulatory commissions, the NETOs (including CL&P, NSTAR Electric and PSNH) and other settling parties, was filed at the FERC. The Settlement Agreement included, among other things, a new formula rate template in which all regional and local transmission revenue requirements will be determined through a single formula rate. The Settlement Agreement was contested by a group of municipal entities and the FERC Trial Staff. On May 22, 2019, FERC rejected the Settlement Agreement and remanded the proceeding for hearings. The partiesParties have been engaged in further settlement negotiations and reached an agreement in principle on October 22, 2019. On June 15, 2020, the NETOs (including CL&P, NSTAR Electric and PSNH) filed an uncontested Settlement Agreement with FERC, which was signed by all six New England state regulatory commissions, New England States Committee on Electricity, New England Municipals and all the NETOs. The Settlement Agreement proposes to implement a new regional and local rate structure effective on January 1, 2021, establishes annual formula rate transparency procedures effective June 15, 2021 and contains a rate moratorium through December 31, 2024. There is no time requirement under which the FERC ~~Chief Administrative Law Judge has approved a suspension of the schedule for ninety days~~must issue an order, which is required for the ~~NETOs~~new formula rate template to ~~review~~go into effect.

U.S. Federal Corporate Income Taxes: Local and regional transmission service rates do not currently reflect amortization of excess ADIT (EDIT) balances that resulted from the ~~terms~~Tax Cuts and Job Act (the Act). On November 15, 2018, FERC issued a Policy Statement and a separate Notice of Proposed Rulemaking addressing accounting and rate issues related to ADIT changes resulting from the Act. On November 21, 2019, FERC issued its final rule requiring public utilities with ~~other active parties~~transmission formula rates to make adjustments to ADIT and ~~finalize and submit~~EDIT. On July 30, 2020, Eversource submitted its filing in compliance with FERC's final rule to address the ~~settlement to FERC.~~EDIT resulting from the Act.

Regulatory Developments and Rate Matters

Electric, Natural Gas and Water Utility Base Distribution Rates: The regulated companies’ distribution rates are set by their respective state regulatory commissions, and their tariffs include mechanisms for periodically adjusting their rates for the recovery of specific incurred costs. Other than as described below, for the first nine months of ~~2019,~~2020, 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 ~~2018~~2019 Form 10-K.

~~U.S. Federal Corporate Income Taxes:~~ COVID-19 Regulatory Dockets:~~On December 22, 2017, the Tax Cuts~~ Beginning in March 2020, Connecticut, Massachusetts and ~~Jobs Act became law, which amended existing federal tax rules to reduce the U.S. federal corporate~~New Hampshire established moratoriums on disconnections of residential and commercial customers for non-payment for utility service. In all three states, a moratorium for lower income tax rate from 35 percent to 21 percent effective January 1, 2018. For our regulated companies, the most significant changes are (1) the benefit of incurring a lower federal income tax expense and (2) the reduction in ADIT liabilities (now excess ADIT or EDIT), which are estimated to be approximately $2.8 billion and included in regulatory liabilities as of September 30, 2019. The refund of these EDIT regulatory liabilities tohardship residential customers will ~~generally be made over~~remain in place through the ~~same period as~~normal state regulated winter moratorium that ends in the spring of 2021. In Connecticut, the moratorium for all remaining ~~useful lives of~~customers has expired, and on October 30, 2020, PURA denied a pending petition to extend the ~~underlying assets that gave rise to~~moratorium for non-hardship residential and small business customers. In Massachusetts, the ~~ADIT liabilities. The refund of EDIT has begun at several of our distribution companies~~moratorium on commercial utility disconnections ended on September 1, 2020 and ~~is reflected in rates. The refund to customers~~the moratorium on residential non-hardship disconnections ends on November 15, 2020. In New Hampshire, the moratorium on residential and ~~resulting amortization of the EDIT regulatory liabilities results in lower Revenues~~commercial utility disconnections ended on the statements of income and lower current tax expense. This is offset by the reduction to Income Tax Expense due to the amortization of the EDIT. The refund of EDIT results in a lower effective tax rate and no impact on net income.July 15, 2020.

In Connecticut, PURA opened a docket to address COVID-19 developments, including issuing orders on March 18, 2020, April 29, 2020 and May 15, 2020 that authorized electric, natural gas and water utilities to establish a regulatory asset for COVID-19 uncollectible customer receivable expenses and costs associated with the related orders. PURA’s April 29, 2020 order, as supplemented on May 15, 2020, also allowed the inclusion of working capital costs in the regulatory asset, and authorized electric, natural gas and water utilities to establish a payment plan program designed to assist any customer who requests financial assistance during the COVID-19 pandemic. On July 10, 2020, PURA denied a request from a coalition of large industrial customers to reduce or suspend certain electric and natural gas charges during the COVID-19 pandemic.

In Massachusetts, on April 17, 2020, a coalition of electric, natural gas and water utilities submitted a comprehensive proposal to the DPU that would enable the state’s utilities to provide flexible payment arrangements to those customers who need financial assistance, while simultaneously maintaining the financial integrity necessary to continue to conduct and finance utility operations through appropriate ratemaking treatment and the establishment of a regulatory asset for COVID-19 related expenses, including uncollectible customer receivable expenses, among other proposals. On May 11, 2020, the DPU opened an inquiry into establishing policies and practices regarding customer assistance and ratemaking measures for electric and natural gas companies in response to the effects of COVID-19. On June 26, 2020, the DPU approved a COVID-19 customer outreach plan. On July 31, 2020, the DPU approved and adopted the coalition’s comprehensive Customer Assistance Plan involving extended payment plans and waiver of late fees, extended plans under available arrearage management plans (“AMPs”), and continuation of the Shut-Off Moratorium. On September 3, 2020, the DPU approved the 2020 small commercial arrearage forgiveness program (“AFP”) proposed by the electric and natural gas distribution companies.

In New Hampshire, on October 5, 2020, the NHPUC approved operating under an agreement governing collections and disconnection activities, deposit activities, flexible payment plans, and special arrangements for income-qualified customers for all New Hampshire utilities including Eversource’s electric and water utilities. Also, on August 18, 2020, the NHPUC Staff recommended that utilities in New Hampshire be permitted to create a regulatory asset for waived fees and incremental bad debt related to the COVID-19 pandemic. The NHPUC has yet to act on that recommendation.

For information on COVID-19-related regulatory deferrals recorded and COVID-19 charges incurred, see "Impact of COVID-19" included in this Management’s Discussion and Analysis.

Storm ~~Restoration Costs, Net:~~ Event:

~~In the second half of 2019, three significant storms, one in July and two in October,~~On August 4, 2020, Tropical Storm Isaias caused ~~extensive~~catastrophic damage to our electric distribution ~~systems~~system, which resulted in significant amounts and ~~significant~~durations of customer outages, ~~across all three states. A~~primarily in Connecticut. In terms of customer outages, this storm ~~must~~was one of the worst in CL&P’s history. PURA has opened an investigation into CL&P's response to Tropical Storm Isaias. PURA will also investigate the prudence of costs incurred by CL&P to restore service as part of its response. CL&P is fully participating in PURA’s investigations and believes that these storm restoration costs were prudently incurred and meet ~~certain criteria to qualify for recovery with~~ the criteria ~~specific~~for cost recovery. As a result, management does not expect the storm costs to ~~each state jurisdiction and utility company. Once~~have a ~~storm qualifies for recovery, all qualifying expenses incurred during storm restoration efforts are deferred and recovered from customers. Costs for storms that do not meet~~material impact on the ~~specific criteria are expensed as incurred. The July 2019~~results of operations of Eversource or CL&P.

Based on current estimates, the storm resulted in ~~qualifying~~deferred storm restoration costs of approximately ~~$16~~$257 million ~~for NSTAR Electric. Management continues~~at CL&P and $276 million at Eversource as of September 30, 2020. The estimated cost of restoration will change as additional cost information becomes available and final storm costs are deferred or capitalized. The majority of incremental storm costs relate to ~~evaluate the~~third-party vendors that are external field crews needed to restore power and address municipal priorities. CL&P’s current estimate of total storm ~~restoration~~ costs includes its projection of the cost of such vendors, but that estimate will change as CL&P receives and examines all storm related invoices. On October ~~2019 storms~~12, 2020, CL&P filed a motion requesting an extension of time to submit a final and ~~believes~~complete report on storm costs to PURA by July 1, 2021. On October 23, 2020, PURA denied this request, and on November 2, 2020, CL&P filed a request for reconsideration of PURA’s ruling.

Connecticut:

CL&P Storm Investigation: On August 7, 2020, PURA issued a notice that it had opened a docket to investigate the preparation for and response to Tropical Storm Isaias by Connecticut utilities, including CL&P. Hearings are currently scheduled to begin on December 14, 2020 and a final decision is expected on April 28, 2021. If the April 28, 2021 final decision concludes that CL&P failed to comply with applicable storm ~~restoration costs~~performance standards, then a separate proceeding will be initiated on May 7, 2021 to examine if and what amount of any civil penalty could potentially be imposed on CL&P, with a final decision currently anticipated on July 14, 2021.

CL&P Rate Suspension: On July 31, 2020, PURA temporarily suspended its June 26, 2020 approval of certain delivery rate components effective July 1, 2020, and ordered CL&P to restore rates to those in effect as of June 30, 2020 in order to allow PURA time to reexamine the rates to ensure that CL&P is not over-collecting revenues in the short-term. Rates were adjusted effective August 1, 2020. PURA indicated that this was due to the convergence of a number of recent events, including the COVID-19 crisis and its corresponding effect on customer energy usage, as well as the warmer than normal weather in July. The impact of the temporary suspension of rates is deferred on our balance sheet and results in an increase to our regulatory assets, with no impact on the statement of income, and an expected delay in the collection of our costs.

On November 3, 2020, PURA issued a proposed final decision in which it adjusted the timing of the annual rate adjustments for ~~all storms were prudent~~the Revenue Decoupling Mechanism Charge, the Transmission Adjustment Clause charge, the Non-Bypassable Federally Mandated Congestion Charge, and ~~meet~~ the ~~criteria for specific cost~~Electric System Improvements Tracker so that these rates take effect on May 1st of each year, as opposed to the current process of adjusting rates each January 1 and July 1. The proposed final decision would also modify the calculation of carrying charges and shift the timing of recovery ~~in Connecticut, Massachusetts and New Hampshire, and that recovery from customers~~to rely on more actual versus forecasted information, among other changes. A final decision is ~~probable through the applicable regulatory recovery processes.~~due to be issued on November 25, 2020.

Massachusetts:

~~Hingham Condemnation:~~NSTAR Gas Rate Case: On October 30, 2020 the DPU approved a base distribution rate increase of $23.0 million effective November 1, 2020, compared to the original request of $38.0 million. NSTAR Gas' 2019 plant additions are allowed recovery beginning on November 1, 2021. Thus, the reduced revenue requirement reflects the removal of this recovery, among other adjustments. The DPU also approved NSTAR Gas' proposal to continue its ongoing Gas System Enhancement Program (GSEP), the inclusion of GSEP investments since 2015 into base rates, and the implementation of a 10-year performance-based ratemaking plan, which includes an inflation-based adjustment mechanism to annual base distribution rates. The decision allows an authorized regulatory ROE of 9.9 percent on a capital structure including 54.77 percent equity. The decision also approves a geothermal pilot program.

Sale of Water System: On ~~April 22, 2019, the town of Hingham, Massachusetts voted to acquire the~~July 31, 2020, we sold our water system and treatment plant that supplies water to the towns of Hingham, Hull and North ~~Cohasset. The acquisition price is currently estimated~~Cohasset to ~~be more than $100~~the town of Hingham, Massachusetts. Net property, plant and equipment of $63.9 million ~~subject to adjustment based~~and goodwill of $23.6 million were included in determining the gain on ~~actual capital investments as legally required and other future closing adjustments. Aquarion will continue to operate the water system during the transition period until~~sale. Proceeds from the sale ~~occurs. The Company is evaluating~~were $110.5 million, with a pre-tax gain of $16.0 million (after-tax gain of $3.5 million) recognized within Operations and Maintenance Expense on the ~~impact~~statement of ~~the sale on its financial statements, which will be recorded when the sale transaction occurs. No loss is expected. The transaction is expected to close~~income in the ~~first~~third quarter of 2020. AsThe assets and liabilities associated with the sale of ~~September 30, 2019, these water distribution assets~~the business were ~~included within Property, Plant and Equipment, Net and goodwill on the balance sheet and were also~~previously reflected in the Water Distribution segment and reporting unit.

New Hampshire:

Distribution Rates: On April 26, 2019, PSNH filed an application with the NHPUC for approval of a temporary annual base distribution rate increase, ~~of approximately $33 million,~~ effective July 1, 2019. On June 27, 2019, the NHPUC approved a settlement agreement that was reached by PSNH, the NHPUC Staff, the Office of the Consumer Advocate, and another settling party, to implement a temporary annual base distribution rate increase of $28.3 million. Although new rates were implemented on August 1, 2019 to customers, the provisions of the temporary base distribution rate increase were effective July 1, 2019. The settlement agreement also permits PSNH to recover approximately $68.5 million in unrecovered storm costs over a five-year period beginning August 1, 2019, with debt carrying charges, which is included in the temporary rate increase.

On May 28, 2019, PSNH filed an application with the NHPUC for a permanent increase in base distribution rates of approximately $70 million, effective July 1, 2020, which includes the temporary rate increase request. The temporary rates are subject to reconciliation based on the outcome of the permanent rate case now before the NHPUC. The NHPUC is permitted up to twelve months to adjudicate the permanent rate application from the date of filing. On April 24, 2020, Governor Sununu issued an emergency order, which extends the maximum adjudication period by six months, for a maximum of 18 months. Temporary rates will remain in effect with a reconciliation of permanent rates retroactive to July 1, 2019 once permanent rates are set.

On October 9, 2020, PSNH filed a settlement agreement on permanent rates between it and all parties to the proceeding. Pursuant to that settlement, PSNH would be permitted a permanent rate increase of approximately $45 million, effective as of January 1, 2021. PSNH is also permitted three step increases, effective January 1, 2021, August 1, 2021, and January 1, 2022, to reflect plant additions in calendar years 2019, 2020 and 2021, respectively. The settlement also sets an authorized regulatory ROE of 9.3 percent with a 54.4 percent common equity ratio in PSNH’s capital structure and provides for a new tracker to recover regulatory assessments, vegetation management costs, property tax costs, and lost distribution revenue attributable to net metering. Hearings commenced at the end of October 2020 and a decision by the NHPUC is expected by the end of November 2020.

Audit Report of Generation Asset Divestiture-Related Costs: On May 15, 2020, the NHPUC Audit Staff issued a final report on the audit of PSNH’s generation asset divestiture-related costs and resulting securitized and stranded costs. The findings in the audit report as well as other aspects of the divestiture process were further investigated by NHPUC Staff through the discovery phase, which was completed in July 2020.

On September 30, 2020, PSNH filed a settlement agreement on the generation asset divestiture-related costs with the NHPUC Audit Staff. The settlement agreement resolves all issues with respect to PSNH’s divestiture of its generating assets and the recovery of $12.0 million of divestiture-related costs above the $635.7 million amount previously securitized. The $12.0 million shall be recovered over a one-year period beginning in February 2021. Hearings are expected to commence in November 2020 and a decision by the NHPUC is expected by the end of 2020. We continue to believe the amounts deferred are probable of recovery.

Legislative and Policy Matters

~~New Hampshire~~Connecticut:: On ~~July~~October 8, ~~2019, the New Hampshire Superior Court approved~~2020, Connecticut enacted Public Act 20-5 (House Bill Number 7006), September Special Session (the Act). The Act, among other things, (1) requires PURA to open a ~~settlement between PSNH~~proceeding by June 1, 2021 to begin to evaluate and ~~the Town~~eventually implement performance based regulation for electric distribution companies, and permits PURA to open a proceeding to consider such regulation for natural gas and water companies; (2) extends deadlines for PURA to issue final decisions in rate cases, change of Bow, New Hampshire, where the town had over-assessed the value of the property owned by PSNH for the 2014 through 2018 property tax years. The result of this settlement was $10.0 million in over-paid property taxes, of which PSNH has received $3.75 million in cash through September 30, 2019. PSNH will receive another cash payment of $0.5 million in December 2019, the balance thereaftercontrol transactions and financing proceedings to be ~~credited against~~more consistent with timeframes in many other U.S. jurisdictions; (3) increases the maximum potential penalty for noncompliance with storm performance standards from 2.5 percent to 4 percent of annual electric distribution company revenue; and (4) directs PURA to open a proceeding by January 1, 2021 to evaluate and decide when bill credits should be paid to electric customers who lose service in future ~~property taxes payable, annually through 2023. In addition, PSNH received the results~~storms, including when waivers of ~~a final decision~~these criteria will be granted to utilities. This law has no impact on ~~a property tax dispute with the City of Portsmouth, which amounted~~storm response, costs or impacts prior to ~~$1 million for the 2015 through 2016 property tax years.~~July 1, 2021.

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 ~~2018~~2019 Form 10-K. There have been no material changes with regard to these critical accounting policies.

Refer to Note 1C, "Summary of Significant Accounting Policies - Impairment of Northern Pass Transmission," to the financial statements for further discussion of critical accounting estimates surrounding impairment analysis.

Other Matters

~~Impairment of Northern Pass Transmission~~: Northern Pass was Eversource's planned 1,090 MW HVDC transmission line that would interconnect from the Québec-New Hampshire border to Franklin, New Hampshire and an associated alternating current radial transmission line between Franklin and Deerfield, New Hampshire. As a result of a final decision received on July 19, 2019 from the New Hampshire Supreme Court, whereby the court issued a decision denying Northern Pass’ appeal and affirming the NHSEC’s evaluation and decision that denied Northern Pass’ siting application on NPT, Eversource concluded that construction of NPT was no longer probable. As a result, substantially all of the capitalized project costs, which totaled $318 million, certain of which are subject to cost reimbursement agreements, were impaired.

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: ~~Refer to~~See Note 9B, "Commitments and Contingencies – Long-Term Contractual

Arrangements," for discussion of material changes to contractual ~~obligations.~~obligations since the Eversource 2019 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 and PSNH's combined Annual Reports on Form 10-K, combined Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and any amendments to those reports may be reviewed. Information contained on the Company's website or that can be accessed through the website is not incorporated into and does not constitute a part of this combined Quarterly Report on Form 10-Q.

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, ~~2019~~2020 and ~~2018~~2019 included in this combined Quarterly Report on Form 10-Q:


	For the Three Months Ended September 30,							For the Nine Months Ended September 30,							For the Three Months Ended September 30,							For the Nine Months Ended September 30,
(Millions of Dollars)	2019		2018		Increase/ (Decrease)			2019		2018		Increase/ (Decrease)			2020		2019		Increase/ (Decrease)			2020		2019		Increase/ (Decrease)
Operating Revenues	$	2,175.8	$	2,271.4	$	(95.6	)	$	6,476.1	$	6,413.2	$	62.9		$	2,343.6	$	2,175.8	$	167.8		$	6,670.5	$	6,476.1	$	194.4
Operating Expenses:
Purchased Power, Fuel and Transmission	730.3		842.3		(112.0		)	2,326.0		2,443.0		(117.0		)	806.3		730.3		76.0			2,313.0		2,326.0		(13.0		)
Operations and Maintenance	331.1		344.5		(13.4		)	994.7		970.9		23.8			332.0		331.1		0.9			1,006.1		994.7		11.4
Depreciation	222.6		208.7		13.9			656.6		612.1		44.5			244.5		222.6		21.9			721.2		656.6		64.6
Amortization	73.9		92.7		(18.8		)	183.8		174.1		9.7			57.5		73.9		(16.4		)	130.7		183.8		(53.1		)
Energy Efficiency Programs	136.8		130.0		6.8			382.8		366.1		16.7			145.0		136.8		8.2			408.8		382.8		26.0
Taxes Other Than Income Taxes	171.9		187.2		(15.3		)	537.7		547.1		(9.4		)	197.1		171.9		25.2			556.7		537.7		19.0
Impairment of Northern Pass Transmission	—		—		—			239.6		—		239.6			—		—		—			—		239.6		(239.6		)
Total Operating Expenses	1,666.6		1,805.4		(138.8		)	5,321.2		5,113.3		207.9			1,782.4		1,666.6		115.8			5,136.5		5,321.2		(184.7		)
Operating Income	509.2		466.0		43.2			1,154.9		1,299.9		(145.0		)	561.2		509.2		52.0			1,534.0		1,154.9		379.1
Interest Expense	135.2		125.2		10.0			399.6		372.7		26.9			134.0		135.2		(1.2		)	403.2		399.6		3.6
Other Income, Net	27.0		16.7		10.3			103.8		100.6		3.2			29.2		27.0		2.2			83.6		103.8		(20.2		)
Income Before Income Tax Expense	401.0		357.5		43.5			859.1		1,027.8		(168.7		)	456.4		401.0		55.4			1,214.4		859.1		355.3
Income Tax Expense	80.2		66.2		14.0			194.5		220.5		(26.0		)	108.2		80.2		28.0			275.6		194.5		81.1
Net Income	320.8		291.3		29.5			664.6		807.3		(142.7		)	348.2		320.8		27.4			938.8		664.6		274.2
Net Income Attributable to Noncontrolling Interests	1.9		1.9		—			5.6		5.6		—			1.9		1.9		—			5.6		5.6		—
Net Income Attributable to Common Shareholders	$	318.9	$	289.4	$	29.5		$	659.0	$	801.7	$	(142.7	)	$	346.3	$	318.9	$	27.4		$	933.2	$	659.0	$	274.2

Operating Revenues

Sales Volumes: A summary of our retail electric GWh sales volumes, our firm natural gas MMcf sales volumes, and our water MG sales volumes, and percentage changes, is as follows:


	Electric					Firm Natural Gas								Water								Electric							Firm Natural Gas						Water
	Sales Volumes (GWh)		Percentage Decrease			Sales Volumes (MMcf)					Percentage Increase			Sales Volumes (MG)						Percentage Decrease		Sales Volumes (GWh)					Percentage Increase/(Decrease)		Sales Volumes (MMcf)				Percentage (Decrease)		Sales Volumes (MG)			Percentage Increase
Three Months Ended September 30:	2019	2018 ⁽¹⁾			2019			2018 ⁽²⁾			Percentage Increase		2019			2018			2020				2019			2020			2019			2020	Percentage (Decrease)		2019			Percentage Increase
Traditional	2,078	2,206	Percentage Decrease	(5.8	)%		—			—		—	%		695			732		Percentage Decrease		(5.1	)%	2,110		2,078	Percentage Increase/(Decrease)		1.5	%	—		—		—	%	770	695		10.8	%
Decoupled and Special Contracts ⁽³⁾	12,261	13,110	(6.5	)%		11,557			11,342		1.9	%		6,961			7,118			(2.2	)%
Decoupled and Special Contracts ⁽¹⁾																						12,281			12,261		0.2	%	11,351		11,557		(1.8	)%	8,102		6,961	16.4	%
Total Sales Volumes	14,339	15,316	(6.4	)%		11,557			11,342		1.9	%		7,656			7,850			(2.5	)%	14,391			14,339		0.4	%	11,351		11,557		(1.8	)%	8,872		7,656	15.9	%

Nine Months Ended September 30:
Traditional	5,803	5,981	(3.0	)%		—			—		—	%		1,604			1,684			(4.8	)%	5,805			5,803		—	%	—		—		—	%	1,686		1,604	5.1	%
Decoupled and Special Contracts ⁽³⁾	33,298	34,690	(4.0	)%		74,915			73,325		2.2	%		16,173			16,491			(1.9	)%
Decoupled and Special Contracts ⁽¹⁾																						32,404			33,298		(2.7	)%	68,920		74,915		(8.0	)%	17,658		16,173	9.2	%
Total Sales Volumes	39,101	40,671	(3.9	)%		74,915			73,325		2.2	%		17,777			18,175			(2.2	)%	38,209			39,101		(2.3	)%	68,920		74,915		(8.0	)%	19,344		17,777	8.8	%


⁽¹⁾	Special contracts are unique to Yankee Gas natural gas distribution customers who take service under such an arrangement and generally specify the amount of distribution revenue to be paid to Yankee Gas regardless of the customers' usage.

⁽¹⁾ ~~Effective February 1, 2018, NSTAR Electric operated entirely under a decoupled rate structure. The 2018~~

Weather, fluctuations in energy supply costs, conservation measures (including utility-sponsored energy efficiency programs), and economic conditions affect customer energy usage and water consumption. Industrial sales volumes ~~for NSTAR Electric have been recast~~are less sensitive to ~~present January 2018 as decoupled to conform to the current year presentation.~~

⁽²⁾ ~~Effective November 15, 2018, Yankee Gas operated under a decoupled rate structure. The 2018~~temperature variations than residential and commercial sales volumes. In our service territories, weather impacts both electric and water sales volumes ~~for Yankee Gas have been recast to present 2018 as decoupled to conform to~~during the ~~current year presentation.~~

⁽³⁾ ~~Special contracts are unique to Yankee Gas~~summer and both electric and natural gas ~~distribution customers who take service under such an arrangement and generally specify~~sales volumes during the ~~amount~~winter; however, natural gas sales volumes are more sensitive to temperature variations than electric sales volumes. Customer heating or cooling usage may not directly correlate with historical levels or with the level of ~~distribution revenue to be paid to Yankee Gas regardless of the customers' usage.~~degree-days that occur.

Fluctuations in retail electric sales volumes at PSNH impact earnings ("Traditional" in the table above). For CL&P, NSTAR Electric, Yankee Gas, ~~and~~ NSTAR Gas and our Connecticut water distribution business, fluctuations in retail sales volumes do not materially impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms ("Decoupled" in the table above). These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized. ~~Fluctuations in water sales volumes largely do not impact earnings as our Connecticut water distribution business is also decoupled.~~

Operating Revenues: Operating Revenues by segment increased/(decreased) for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018,~~2019, as follows:


(Millions of Dollars)	Three Months Ended			Nine Months Ended			Three Months Ended			Nine Months Ended
Electric Distribution	$	(95.8	)	$	5.4		$	128.7		$	154.7
Natural Gas Distribution	(5.6		)	39.4			6.8			(9.9		)
Electric Transmission	17.2			84.9			41.5			97.7
Water Distribution	0.7			2.0			(0.1		)	3.1
Other	33.5			74.6			64.2			133.6
Eliminations	(45.6		)	(143.4		)	(73.3		)	(184.8		)
Total Operating Revenues	$	(95.6	)	$	62.9		$	167.8		$	194.4

Electric and Natural Gas Distribution Revenues:

Base Distribution Revenues:

Base electric distribution revenues increased ~~$33.3~~$23.3 million and ~~$72.5~~$87.2 million for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018,~~2019, respectively, due primarily to the impact of CL&P's base distribution rate increases effective May 1, ~~2019~~2020 and May 1, ~~2018,~~2019, which include recovery of storm costs and certain other items that do not impact earnings, the impact of a PSNH temporary base distribution rate increase effective July 1, 2019, which includes recovery of storm costs and certain other items that do not impact earnings, and an NSTAR Electric base distribution rate increase effective January 1, ~~2019, and a PSNH base distribution rate increase effective July 1, 2019.~~2020.

Base natural gas distribution revenues ~~decreased $4.1~~increased $3.1 million and ~~increased $12.6~~$15.1 million for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018, respectively. These fluctuations are~~2019, respectively, due primarily to ~~the seasonality of the decoupled rate structure arising from the Yankee Gas~~a base distribution rate ~~case that provides lower revenues in non-heating months (and greater revenues in the winter heating months).~~increase at Yankee Gas effective January 1, 2020.

Tracked Distribution Revenues: Tracked distribution revenues consist of certain costs that are recovered from customers in retail rates through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs ~~have~~has no impact on earnings. However, tracked revenues do include certain incentives earned, return on rate base and on capital tracking mechanisms, and carrying charges that are billed in rates to customers, which do impact earnings. Costs recovered through cost tracking mechanisms include, among others, energy supply and natural gas supply procurement and other energy-related costs, ~~and~~ electric retail transmission charges, ~~which decreased significantly due primarily to the lower federal corporate income tax rate that was reflected effective January 1, 2019. In addition, cost tracking mechanisms include~~ energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), and additionally for NSTAR Electric, pension and PBOP benefits and net metering for distributed generation. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties. ~~However, tracked revenues do include certain incentives earned, return on rate base, and carrying charges that are billed in rates to customers, which do impact earnings.~~

Tracked distribution revenues increased/(decreased) for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018,~~2019, due primarily to the following:


	Electric Distribution						Natural Gas Distribution					Electric Distribution						Natural Gas Distribution
(Millions of Dollars)	Three Months Ended			Nine Months Ended			Three Months Ended			Nine Months Ended		Three Months Ended			Nine Months Ended			Three Months Ended			Nine Months Ended
Retail Tariff Tracked Revenues
Retail Tariff Tracked Revenues:
Energy supply procurement	$	(48.1	)	$	45.6		$	0.9		$	23.0	$	(29.3	)	$	(171.6	)	$	(4.1	)	$	(38.9	)
Retail transmission	(37.7		)	(110.8		)	N/A			N/A
Stranded cost recovery	(11.0		)	2.9			N/A			N/A
CL&P FMCC												51.4			92.2			—			—
Other distribution tracking mechanisms	(5.2		)	21.7			2.0			5.9		28.4			35.5			4.2			27.1
Wholesale Market Sales Revenue	(15.7		)	(17.5		)	(5.9		)	0.2		46.5			107.2			3.2			(9.7		)

The decrease in energy supply procurement within electric distribution was driven primarily by lower average prices, partially offset by higher average supply-related sales volumes for the three and nine month periods. The increase in the CL&P FMCC regulatory tracking mechanism revenues and the increase in wholesale market sales revenue within electric distribution was due primarily to the new Millstone PPA entered into by CL&P in 2019, as required by regulation. Beginning in the fourth quarter of 2019, CL&P sells the energy purchased from Millstone Nuclear Power Station (Millstone) into the wholesale market and uses the proceeds from the energy sales to offset a portion of the contract costs. The net costs under the contract are recovered from customers in the FMCC rate.

Electric Transmission Revenues: Electric transmission revenues increased ~~$17.2~~$41.5 million and ~~$84.9~~$97.7 million for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018, respectively,~~2019, due primarily to continued investment in our transmission infrastructure. Electric transmission revenues also increased for the nine months ended September 30, 2020 as compared to the same period in 2019, as a result of a higher benefit from the annual billing and cost reconciliation filing with FERC.

Other Revenues and Eliminations: Other revenues primarily include the revenues of Eversource's service company, most of which are eliminated in consolidation. Eliminations are also primarily related to the Eversource electric transmission revenues that are derived

from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the

wholesale transmission business.

Purchased Power, Fuel and Transmission expense includes costs associated with purchasing electricity and natural gas on behalf of our customers. These electric and natural gas supply costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs).

Purchased Power, Fuel and Transmission expense increased/(decreased) for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018,~~2019, due primarily to the following:


(Millions of Dollars)	Three Months Ended			Nine Months Ended			Three Months Ended			Nine Months Ended
Electric Distribution	$	(50.7	)	$	33.5
Natural Gas Distribution	(6.3		)	22.9
Transmission	(43.1		)	(107.6		)
Purchased Power Costs							$	77.7		$	100.8
Natural Gas Costs							(0.7		)	(46.1		)
Transmission Costs							14.1			(4.1		)
Eliminations	(11.9		)	(65.8		)	(15.1		)	(63.6		)
Total Purchased Power, Fuel and Transmission	$	(112.0	)	$	(117.0	)	$	76.0		$	(13.0	)

The ~~decrease~~increase in purchased power expense at the electric distribution business for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same ~~period~~periods in ~~2018,~~2019, was driven primarily by ~~lower~~the impact of energy purchases from the new Millstone PPA and higher average supply-related sales volumes, partially offset by ~~higher~~lower average ~~prices associated with the procurement of energy supply.~~prices. The decrease in natural gas supply costs at our natural gas distribution business for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same ~~period~~periods in ~~2018,~~2019, was due primarily to lower average prices ~~partially offset by higher~~and lower average sales volumes.

The increase in ~~purchased power expense at the electric distribution business~~transmission costs for the ~~nine~~three months ended September 30, ~~2019,~~2020, as compared to the same period in 2018, was driven primarily by higher prices associated with the procurement of energy supply. The increase in natural gas supply costs at our natural gas distribution business for the nine months ended September 30, 2019, ~~as compared to the same period in 2018, was due primarily to higher average sales volumes.~~

~~The decrease in transmission costs for the three and nine months ended September 30, 2019, as compared to the same periods in 2018,~~ was primarily the result of an increase in Local Network Service charges, which reflects the cost of transmission service provided by Eversource over our local transmission network and an increase in costs billed by ISO-NE that support regional grid investments. This was partially offset by a decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to ~~customers,~~customers. The decrease in transmission costs for the nine months ended September 30, 2020, as compared to the same period in 2019, was primarily the result of a decrease in the retail transmission cost deferral. This was partially offset by an increase in Local Network Service charges and ~~a decrease~~an increase in costs billed by ISO-NE that support regional grid investments. In addition, the decrease in transmission costs was a result of a decrease in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network. Effective January 1, 2019, the retail transmission rate was adjusted to reflect the lower federal corporate income tax rate, resulting in a decrease in the cost of retail transmission service.

Operations and Maintenance expense includes tracked costs and costs that are part of base electric, natural gas and water distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense ~~increased/(decreased)~~increased for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018,~~2019, due primarily to the following:


(Millions of Dollars)	Three Months Ended			Nine Months Ended			Three Months Ended			Nine Months Ended
Base Electric Distribution (Non-Tracked Costs):
Employee-related expenses, including labor and benefits	$	(16.7	)	$	(25.3	)	$	(4.3	)	$	(14.1	)
Storm Restoration Costs							10.1			8.6
Operations-related expenses, including vegetation management, vehicles, and outside services	(1.9		)	23.9			(4.2		)	1.8
Storm Restoration Costs	9.3			13.3
Shared corporate costs (including computer software depreciation at Eversource Service)							7.2			17.9
COVID-19 Costs							1.9			8.6
Other non-tracked operations and maintenance	(4.7		)	(13.6		)	(1.5		)	(2.3		)
Total Base Electric Distribution (Non-Tracked Costs)	(14.0		)	(1.7		)	9.2			20.5
Base Natural Gas Distribution (Non-Tracked Costs)	2.7			10.6			0.3			2.7
Water Distribution	(0.5		)	0.6
Tracked Costs (Electric Distribution, Electric Transmission and Natural Gas Distribution) - Increase due primarily to higher electric transmission expenses, partially offset by the absence in 2019 of PSNH generation operations expenses due to the 2018 sales of thermal and hydroelectric generation assets	11.2			42.3
Water Distribution:
Gain on sale of Hingham water system							(16.0		)	(16.0		)
Other							0.7			0.6
Total Water Distribution							(15.3		)	(15.4		)
Tracked Costs (Electric Distribution, Electric Transmission and Natural Gas Distribution)							16.0			23.3
Other and eliminations:
Eversource Parent and Other Companies - other operations and maintenance	75.8			102.9			(11.7		)	33.4
Acquisition costs related to CMA							7.4			17.6
Eliminations	(88.6		)	(130.9		)	(5.0		)	(70.7		)
Total Operations and Maintenance	$	(13.4	)	$	23.8		$	0.9		$	11.4

Depreciation expense increased for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018,~~2019, due ~~primarily~~ to higher utility plant in service ~~balances and new depreciation rates effective with the 2018 CL&P distribution rate case settlement agreement.~~balances.

Amortization expense includes the deferral of energy supply, ~~and~~ energy-related costs and other costs that are included in certain regulatory commission-approved cost tracking mechanisms, and the amortization of certain ~~costs.~~costs as those costs are collected in rates. This deferral adjusts expense to match the corresponding revenues. Energy supply and energy-related costs are recovered from customers in rates and have no impact on earnings. Amortization decreased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the deferral of energy supply and energy-related ~~costs, partially offset by increased amortization of PSNH's securitized regulatory asset related to the 2018 RRB issuance of $0.6 million.~~

costs. Amortization ~~expense increased~~decreased for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due ~~primarily~~ to ~~an increase in storm cost~~the under recovery of energy purchases related to the Millstone PPA at CL&P and ~~NSTAR Electric, and increased amortization of PSNH's securitized regulatory asset related~~due to the ~~2018 RRB issuance~~deferral of ~~$15.1 million.~~energy supply and energy-related costs.

Energy Efficiency Programs expense increased for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018,~~2019, due primarily to ~~higher spending for~~the deferral adjustment at CL~~&P's~~&P, PSNH and ~~PSNH's~~NSTAR Gas, which reflects the actual costs of energy efficiency programs compared to the amounts billed to customers and the timing of the recovery of energy efficiency costs. The increase was partially offset by a decrease in spending on certain large energy efficiency projects in 2020 compared to 2019 at NSTAR Electric due to timing. The costs for the majority of the state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates ~~most of which~~and have no impact on earnings.

Taxes Other Than Income Taxes expense ~~decreased~~increased for the three and nine months ended September 30, ~~2019,~~2020, as compared to the same periods in ~~2018,~~2019, due primarily to an increase in property taxes as a result of higher utility plant balances and higher Connecticut gross earnings taxes. The increase for the nine month period was partially offset by a decrease of ~~$10.7~~$21.4 million ~~and $14.7 million, respectively,~~ related to CL&P's remittance of energy efficiency funds to the State of Connecticut. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. The decrease is also due to amounts received by PSNH in the third quarter of 2019 relating to a refund of property taxes as a result of a settlement with the town of Bow, New Hampshire ($8.3 million), and a decrease in NSTAR Electric's property taxes due to a decrease in tax rates.

~~Impairment of Northern Pass Transmission~~ reflects an impairment charge of $239.6 million that was recorded in the second quarter of 2019 as a result of the July 19, 2019 New Hampshire Supreme Court decision. The after-tax impact of this impairment charge was $204.4 million. For further information on the impairment of NPT, see "Other Matters - Impairment of Northern Pass Transmission" in this ~~Management's Discussion and Analysis of Financial Condition and Results of Operations~~.

Interest Expense ~~increased~~decreased for the three ~~and~~months ended September 30, 2020, as compared to the same period in 2019, due primarily to a decrease in interest on notes payable ($4.5 million), partially offset by an increase in interest on long-term debt as a result of new debt issuances ($3.6 million). Interest Expense increased for the nine months ended September 30, ~~2019,~~2020, as compared to the same ~~periods~~period in ~~2018,~~2019, due primarily to an increase in interest on long-term debt as a result of new debt issuances ($~~14.8 million~~17.0 million) and ~~$26.1 million, respectively)~~higher amortization of debt discounts and premiums, net ($3.5 million), ~~an increase in interest on the 2018 PSNH RRB issuance ($7.1 million, for the nine months) and an increase~~partially offset by a decrease in interest on notes payable ($~~5.6 million, for the nine months). Partially offsetting these increases was~~13.0 million), and an increase in AFUDC related to debt funds and other capitalized interest ($~~6.9 million and $17.9 million, respectively)~~3.1 million).

Other Income, Net increased for the three ~~and nine~~ months ended September 30, ~~2019,~~2020, as compared to the same ~~periods~~period in ~~2018,~~2019, due primarily to ~~an increase~~investment income in 2020 compared to investment losses in 2019 driven by market volatility ($3.8 million) and a gain on the sale of property ($1.5 million), partially offset by a decrease in equity in earnings ~~of unconsolidated affiliates~~ related to Eversource's equity method investments ($~~34.0 million~~2.2 million) and ~~$37.4 million, respectively)~~lower interest income ($1.4 million). In

Other Income, Net decreased for the ~~third quarter of 2018, Eversource recognized~~nine months ended September 30, 2020, as compared to the same period in 2019, due primarily to a ~~$32.9 million other-than-temporary impairment charge~~decrease in equity in earnings related to ~~our~~Eversource's equity method investment in the Access Northeast project, which was reflected as a loss within equity in earnings. Partially offsetting these increases was a decrease related to pension, SERP and PBOP non-service income componentsinvestments ($~~4.7 million and $21.4 million, respectively)~~23.2 million), the absence in ~~2019~~2020 of a gain on sale of property ($4.4 million, for the three and nine months), investment losses in 2019 compared to investment income in 2018 ($4.6 million and $4.5 million, respectively) and a decrease in the recognition of the equity component of the carrying charges related to PSNH storm costs recorded in interest income ~~at PSNH~~in the first quarter of 2019 ($~~8.7 million~~5.2 million) and ~~$3.5 million, respectively)~~lower AFUDC related to equity funds ($2.7 million), partially offset by an increase related to pension, SERP and PBOP non-service income components ($11.1 million).

Income Tax Expense increased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to higher pre-tax earnings ($8.3 million), higher state taxes ($6.4 million), by a decrease in tax planning benefits ($9.5 million), a decrease in amortization of EDIT ($0.1 million), the ~~absence~~sale of ~~an aggregate benefit relating to both federal~~Hingham water system ($12.5 million), a decrease in share-based payment excess tax ~~reform~~benefits ($0.1 million), and a ~~tax reserve in 2018~~return to provision adjustment ($183.0 million), ~~the absence of the impairment of Access Northeast~~partially offset by an increase in ~~2018 ($6.9 million),~~ items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($~~5.6~~2.1 million), and ~~higher pre-tax earnings ($2.8 million). The~~the absence in 2020 of an increase ~~was partially offset by amortization of EDIT~~in valuation allowance ($9.8 million) ~~and tax planning ($9.5 million)~~. The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is $13.5 million offset by current tax benefits of $3.7 million and amortization of EDIT of $9.8 million, for the three months ended September 30, 2019, which results in no impact on earnings.

Income Tax Expense ~~decreased~~increased for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to higher pre-tax earnings ($21.0 million), higher state taxes ($16.2 million), by the absence in 2020 of the impairment of NPT ~~in 2019~~ ($35.2 million), by a decrease in tax planning benefits ($9.5 million), the sale of Hingham water system ($12.5 million), return to provision adjustments ($3.0 million), and an increase in flow-through items and permanent differences ($1.3 million), partially offset by an increase in share-based payment excess tax benefits ($5.1 million), an increase in amortization of EDIT ($26.9 million), and tax planning ($9.5 million). The decrease was partially offset by the absence of an aggregate benefit relating to both federal tax reform and a tax reserve in 2018 ($18 million), items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($12.1 million), higher pre-tax earnings ($8.62.7 million), and the absence in 2020 of ~~the impairment of Access Northeast~~an increase in ~~2018~~valuation allowance ($~~6.9~~9.8 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is $37.0 million offset by current tax benefits of $10.1 million and amortization of EDIT of $26.9 million, for the nine months ended September 30, 2019, which results in no impact on earnings.

RESULTS OF OPERATIONS –

THE CONNECTICUT LIGHT AND POWER COMPANY

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P, NSTAR Electric and PSNH for the nine months ended September 30, ~~2019~~2020 and ~~2018~~2019 included in this combined Quarterly Report on Form 10-Q:


	For the Nine Months Ended September 30,																					For the Nine Months Ended September 30,
	CL&P							NSTAR Electric							PSNH							CL&P							NSTAR Electric							PSNH
(Millions of Dollars)	2019		2018		Increase/ (Decrease)			2019		2018		Increase/ (Decrease)			2019		2018		Increase/ (Decrease)			2020		2019		Increase/ (Decrease)			2020		2019		Increase/ (Decrease)			2020		2019		Increase/ (Decrease)
Operating Revenues	$	2,444.0	$	2,344.9	$	99.1		$	2,358.2	$	2,400.3	$	(42.1	)	$	797.8	$	792.7	$	5.1		$	2,711.4	$	2,444.0	$	267.4		$	2,270.2	$	2,358.2	$	(88.0	)	$	815.3	$	797.8	$	17.5
Operating Expenses:
Purchased Power, Fuel and Transmission	865.4		850.8		14.6			859.2		981.9		(122.7		)	300.7		294.0		6.7
Purchased Power and Transmission																						1,089.2		865.4		223.8			702.1		859.2		(157.1		)	273.3		300.7		(27.4		)
Operations and Maintenance	399.1		355.5		43.6			342.8		344.5		(1.7		)	156.2		153.3		2.9			417.7		399.1		18.6			369.3		342.8		26.5			151.8		156.2		(4.4		)
Depreciation	224.1		208.9		15.2			220.3		205.2		15.1			69.7		69.5		0.2			238.7		224.1		14.6			238.2		220.3		17.9			74.5		69.7		4.8
Amortization of Regulatory Assets, Net	78.5		97.4		(18.9		)	73.1		35.5		37.6			39.9		41.3		(1.4		)	37.2		78.5		(41.3		)	69.1		73.1		(4.0		)	39.0		39.9		(0.9		)
Energy Efficiency Programs	86.9		71.6		15.3			227.0		229.4		(2.4		)	20.2		15.7		4.5			109.7		86.9		22.8			210.7		227.0		(16.3		)	29.2		20.2		9.0
Taxes Other Than Income Taxes	261.1		267.7		(6.6		)	144.4		145.7		(1.3		)	50.6		59.8		(9.2		)	260.6		261.1		(0.5		)	154.1		144.4		9.7			58.4		50.6		7.8
Total Operating Expenses	1,915.1		1,851.9		63.2			1,866.8		1,942.2		(75.4		)	637.3		633.6		3.7			2,153.1		1,915.1		238.0			1,743.5		1,866.8		(123.3		)	626.2		637.3		(11.1		)
Operating Income	528.9		493.0		35.9			491.4		458.1		33.3			160.5		159.1		1.4			558.3		528.9		29.4			526.7		491.4		35.3			189.1		160.5		28.6
Interest Expense	112.3		113.1		(0.8		)	85.4		80.8		4.6			44.6		44.0		0.6			115.0		112.3		2.7			95.0		85.4		9.6			44.1		44.6		(0.5		)
Other Income, Net	11.6		20.7		(9.1		)	32.5		40.6		(8.1		)	14.6		24.3		(9.7		)	16.3		11.6		4.7			38.2		32.5		5.7			10.9		14.6		(3.7		)
Income Before Income Tax Expense	428.2		400.6		27.6			438.5		417.9		20.6			130.5		139.4		(8.9		)	459.6		428.2		31.4			469.9		438.5		31.4			155.9		130.5		25.4
Income Tax Expense	101.2		102.0		(0.8		)	99.8		112.2		(12.4		)	30.0		37.9		(7.9		)	103.5		101.2		2.3			106.3		99.8		6.5			37.5		30.0		7.5
Net Income	$	327.0	$	298.6	$	28.4		$	338.7	$	305.7	$	33.0		$	100.5	$	101.5	$	(1.0	)	$	356.1	$	327.0	$	29.1		$	363.6	$	338.7	$	24.9		$	118.4	$	100.5	$	17.9

Operating Revenues

Sales Volumes: A summary of our retail electric GWh sales volumes is as follows:


	For the Nine Months Ended September 30,						For the Nine Months Ended September 30,
	2019	2018	Decrease		Percentage Decrease		2020	2019	Increase/(Decrease)		Percentage Decrease
CL&P	15,681	16,376	(695	)	(4.2	)%	15,318	15,681	(363	)	(2.3	)%
NSTAR Electric	17,617	18,314	(697	)	(3.8	)%	17,086	17,617	(531	)	(3.0	)%
PSNH	5,803	5,981	(178	)	(3.0	)%	5,805	5,803	2		—	%

Fluctuations in retail electric sales volumes at PSNH impact earnings. For CL&P and NSTAR Electric, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms.

Operating Revenues: Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, increased ~~$99.1~~$267.4 million at CL&P and ~~$5.1~~$17.5 million at PSNH, and decreased ~~$42.1~~$88.0 million at NSTAR Electric, for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018.~~2019.

Base Distribution Revenues:

CL&P's distribution revenues increased ~~$47.9~~$31.7 million due primarily to the impact of its base distribution rate increases effective May 1, ~~2019~~2020 and May 1, ~~2018,~~2019, which include recovery of storm costs and certain other items that do not impact earnings.

NSTAR Electric's distribution revenues increased ~~$17.5~~$25.9 million due primarily to the impact of its base distribution rate increase effective January 1, ~~2019.~~

2020.

PSNH's distribution revenues increased ~~$7.1~~$29.6 million due primarily to the impact of its temporary base distribution rate increase effective July 1, ~~2019.~~

2019, which includes recovery of storm costs and certain other items that do not impact earnings.

Tracked Revenues: Tracked distribution revenues consist of certain costs that are recovered from customers in retail rates through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs ~~have~~has no impact on earnings. However, tracked revenues do include certain incentives earned, return on rate base and on capital tracking mechanisms, and carrying charges that are billed in rates to customers, which do impact earnings. Costs recovered through cost tracking mechanisms include, among others, energy supply procurement and other energy-related costs, ~~and~~ retail transmission charges, ~~which decreased significantly due primarily to the lower federal corporate income tax rate that was reflected effective January 1, 2019. In addition, cost tracking mechanisms include~~ energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), and additionally for NSTAR Electric, pension and PBOP benefits and net metering for distributed generation. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties. ~~However, tracked revenues do include certain incentives earned, return on rate base, and carrying charges that are billed in rates to customers, which do impact earnings.~~

Tracked revenues increased/(decreased) for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:


(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Retail Tariff Tracked Revenues
Retail Tariff Tracked Revenues:
Energy supply procurement	$	44.3		$	(7.6	)	$	8.9		$	(47.6	)	$	(98.2	)	$	(25.8	)
Retail transmission	(15.8		)	(73.8		)	(21.2		)
Stranded cost recovery	(10.7		)	4.3			9.3
CL&P FMCC										92.2			—			—
Other distribution tracking mechanisms	3.6			11.8			6.3			38.6			(12.3		)	9.2
Wholesale Market Sales Revenue	5.3			(0.5		)	(23.9		)	124.3			(16.1		)	(1.0		)

~~PSNH's~~The decrease in energy supply procurement at CL&P and PSNH reflects lower average prices, partially offset by higher average supply-related sales volumes for the nine months ended September 30, 2020, as compared to the same period in 2019. The decrease in energy supply procurement at NSTAR Electric reflects both lower average prices and lower average supply-related sales volumes for the nine months ended September 30, 2020, as compared to the same period in 2019.

The increase in the CL&P FMCC regulatory tracking mechanism revenues ~~include~~and the ~~absence~~increase in wholesale market sales revenue was due primarily to the new Millstone PPA entered into by CL&P in 2019, as required by regulation. Beginning in the fourth quarter of 2019, CL&P sells the energy purchased from Millstone into the wholesale market and uses the proceeds from the energy sales to offset a portion of the ~~recovery of generation rate base return due to~~contract costs. The net costs under the ~~sale of its thermal and hydroelectric generation assets~~contract are recovered from customers in ~~2018. Revenues from CL&P's other distribution tracking mechanisms include higher earnings from its capital tracker mechanism effective July 1, 2018 due to increased electric system improvements.~~the FMCC rate.

Transmission Revenues: Transmission revenues increased ~~$55.2~~$35.0 million at CL&P, ~~$13.5~~$41.9 million at NSTAR Electric, and ~~$16.2~~$20.8 million at PSNH for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to a higher transmission rate base as a result of continued investment in our transmission ~~infrastructure.~~infrastructure and a higher benefit from the annual billing and cost reconciliation filing with FERC.

Eliminations: Eliminations are primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business. The impact of eliminations decreased revenues by ~~$25.1~~$8.8 million at CL&P, ~~$4.7~~$33.0 million at NSTAR Electric and ~~increased revenues by $1.5~~$13.5 million at PSNH for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018.~~2019.

Purchased Power ~~Fuel~~ and Transmission expense includes costs associated with purchasing electricity on behalf of CL&P, NSTAR Electric and PSNH's customers. These energy supply costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power ~~Fuel~~ and Transmission expense increased/(decreased) for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:


(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Purchased Power Costs	$	54.2		$	(45.2	)	$	24.5		$	254.6		$	(123.3	)	$	(30.5	)
Transmission Costs	(15.1		)	(73.1		)	(19.4		)	(19.9		)	(0.9		)	16.7
Eliminations	(24.5		)	(4.4		)	1.6			(10.9		)	(32.9		)	(13.6		)
Total Purchased Power, Fuel and Transmission	$	14.6		$	(122.7	)	$	6.7
Total Purchased Power and Transmission										$	223.8		$	(157.1	)	$	(27.4	)

Purchased Power Costs: Included in purchased power costs are the costs associated with providing electric generation service supply to all customers who have not migrated to third party ~~suppliers.~~suppliers and the cost of energy purchase contracts, as required by regulation.

The increase at CL&P was due primarily to ~~an increase in~~ the ~~price of power procured on behalf of our customers.~~new Millstone PPA energy purchases and higher average supply-related sales volumes, partially offset by lower average prices.

The decrease at NSTAR Electric was due primarily to ~~a decrease in~~lower expense related to the ~~volume~~procurement of ~~power procured on behalf of our customers.~~energy supply resulting from lower average prices and lower average supply-related sales volumes.

The ~~increase~~decrease at PSNH was due primarily to lower expense related to the procurement of energy supply resulting from lower average prices, partially offset by higher ~~purchased power energy expenses that are recovered as a component of the Energy Service tracking mechanism.~~average supply-related sales volumes.

Transmission Costs: Included in transmission costs are charges that recover the cost of transporting electricity over high-voltage lines from generation facilities to substations, including costs allocated by ISO-NE to maintain the wholesale electric market.

The decrease in transmission costs at CL&P and NSTAR Electric ~~and PSNH~~ was due primarily to a reduction to the retail transmission ~~rate that~~cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers. This was ~~adjusted to reflect the lower federal corporate income tax rate, effective January 1, 2019, resulting~~partially offset by an increase in ~~a decrease in~~Local Network Service charges, which reflects the cost of ~~retail~~ transmission ~~service. In addition, the decrease in~~service provided by Eversource over our local transmission ~~costs at CL&P, NSTAR Electric~~network, and ~~PSNH was primarily a result of a decrease~~an increase in costs billed by ISO-NE that support regional grid investments.

The increase in transmission costs at PSNH was primarily the result of an increase in Local Network Service charges and an increase in costs billed by ISO-NE that support regional grid investments. This was partially offset by a decrease in the retail transmission cost deferral.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense increased/(decreased) for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:


(Millions of Dollars)	CL&P			NSTAR Electric			PSNH			CL&P			NSTAR Electric			PSNH
Base Electric Distribution (Non-Tracked Costs):
Employee-related expenses, including labor and benefits	$	(9.5	)	$	(12.2	)	$	(3.6	)	$	1.0		$	(13.2	)	$	(1.9	)
Storm Restoration Costs										7.2			0.4			1.0
Operations-related expenses, including vegetation management, vehicles, and outside services	8.2			8.7			7.0			(1.5		)	1.9			1.4
Storm restoration costs	5.3			7.8			0.2
Shared corporate costs (including computer software depreciation at Eversource Service)										7.1			8.5			2.3
COVID-19 Costs										3.6			3.5			1.5
Other non-tracked operations and maintenance	4.4			(16.3		)	(1.7		)	(4.6		)	2.8			(0.5		)
Total Base Electric Distribution (Non-Tracked Costs)	8.4			(12.0		)	1.9			12.8			3.9			3.8
Tracked Costs:
Absence in 2019 of PSNH generation operations expenses due to the 2018 sales of thermal and hydroelectric generation assets	—			—			(9.4		)
Transmission expenses	29.2			1.9			3.8			(2.1		)	7.1			(2.0		)
Other tracked operations and maintenance	6.0			8.4			6.6			7.9			15.5			(6.2		)
Total Tracked Costs	35.2			10.3			1.0			5.8			22.6			(8.2		)
Total Operations and Maintenance	$	43.6		$	(1.7	)	$	2.9		$	18.6		$	26.5		$	(4.4	)

Depreciation increased for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018, due primarily to the following:~~

~~The increase at~~2019, for CL&P, ~~was~~NSTAR Electric and PSNH due to higher net plant in service ~~balances and the implementation of new depreciation rates effective with the 2018 CL&P distribution rate case settlement agreement.~~

~~The increase at NSTAR Electric was due to higher net plant in service~~ balances.

~~The increase at NSTAR Electric~~ Amortization of Regulatory Assets, Net decreased for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:

The decrease at CL&P was due primarily to ~~an increase in both storm cost~~the under recovery of energy purchases related to the Millstone PPA and ~~costs associated with low income customers. The remaining increases in amortization was 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.

The decrease at ~~CL&P and PSNH for the nine months ended September 30, 2019, as compared~~NSTAR Electric was due to the ~~same period in 2018, was due primarily to the~~ deferral ~~adjustment~~ of energy supply and energy-related costs, ~~partially offset by an increase in storm cost recovery. The decrease at PSNH is also partially offset by $15.1 million~~which can fluctuate from period to period based on the timing of ~~higher amortization of PSNH's securitized regulatory asset~~costs incurred and related rate changes to ~~the 2018 RRB issuance.~~recover these costs.

The increase at CL&P and PSNH was due to ~~higher spending for~~the deferral adjustment, which reflects actual costs of energy efficiency ~~programs.~~programs compared to the estimated amounts billed to customers and the timing of the recovery of energy efficiency costs.

The decrease at NSTAR Electric was due to the timing of spending on certain large energy efficiency projects in 2020, as compared to 2019.

Taxes Other Than Income Taxes increased/decreased for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:

The decrease ~~of $14.7 million~~ at CL&P was related to a $21.4 million decrease in the remittance of energy efficiency funds to the State of Connecticut. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut. The decrease was partially offset by higher property taxes as a result of a higher utility plant ~~balances and~~balance, higher gross earnings taxes, ~~(the costs~~and the absence in 2020 of ~~which are tracked).~~a use tax refund received in 2019.

The ~~decrease~~increases at NSTAR Electric ~~was~~and PSNH were due to ~~lower~~higher property taxes as a result of ~~a decrease in tax rates.~~

~~The decrease at PSNH was due to a refund of property taxes as a result of a settlement with the town of Bow, New Hampshire ($8.3 million).~~

higher utility plant balances.

Interest Expense ~~decreased/increased~~increased/decreased for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:

The ~~decrease~~increase at CL&P was due to ~~lower~~higher interest on long-term debt ($~~3.5~~6.2 million), partially offset by ~~an increase~~a decrease in interest expense on regulatory deferrals ($~~2.5~~1.0 million), lower amortization of debt discounts and premiums, net ($1.0 million) and a decrease in interest on short-term notes payable ($0.9 million).


•	The increase at NSTAR Electric was due to higher interest on long-term debt ($~~4.8~~8.9 million), an increase in interest expense on regulatory deferrals ($4.6 million), and a decrease in AFUDC related to debt funds ($1.6 million), partially offset by a decrease in interest on short-term notes payable ($3.3 million).

The ~~increase~~decrease at PSNH was due to ~~an increase~~a decrease in RRB interest ~~on the 2018 PSNH RRB issuance~~expense ($~~7.1~~1.0 million), partially offset by ~~lower~~higher interest on long-term debt ($~~1.2~~0.6 million)~~, a decrease in interest on notes payable ($1.8 million), a decrease in interest related to regulatory deferrals ($1.6 million) and an increase in AFUDC related to debt funds ($1.2 million)~~.

Other Income, Netincreased/decreased for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:

~~The decrease~~


•	The increase at CL&P was due primarily to an increase related to pension, SERP and PBOP non-service income components ($2.9 million) and an increase in AFUDC related to equity funds ($2.0 million).

The increase at NSTAR Electric was due primarily to ~~a decrease~~an increase related to pension, SERP and PBOP non-service income components ($~~7.2 million).~~

~~The decrease at NSTAR Electric was due to a decrease related to pension, SERP and PBOP non-service income components ($8.8~~4.2 million) and ~~investment losses in 2019 compared to investment income in 2018 ($2.1 million), partially offset by~~ an increase in AFUDC related to equity funds ($~~3.2~~1.1 million).

The decrease at PSNH was due primarily to the absence in ~~2019~~2020 of ~~a gain on the sale of property ($4.4 million), a decrease in~~ the recognition of the equity component of the carrying charges related to storm costs recorded in interest income in 2019 ($~~3.5~~5.2 million) ~~and a decrease~~, partially offset by an increase related to pension, SERP and PBOP non-service income components ($~~2.9~~1.7 million)~~. Partially offsetting these decreases was~~ and an increase in AFUDC related to equity funds ($~~2.1~~1.4 million).

Income Tax Expense ~~decreased~~increased for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:

The ~~decrease~~increase at CL&P was due primarily to ~~amortization of EDIT~~higher pre-tax earnings ($~~3.6~~6.6 million), higher state taxes ($2.4 million), return to provision adjustments ($1.1 million), and by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($~~3.1~~3.3 million), partially offset by an increase in share-based payment excess tax benefits ($1.8 million), and the absence in 2020 of an increase in the valuation allowance ($9.3 million).

The increase at NSTAR Electric was due primarily to higher pre-tax earnings ($6.6 million), higher state taxes ($2.1 million), and return to provision ~~items~~adjustments ($3 million), partially offset by higher pre-tax earnings ($5.8 million) and higher state taxes ($3.1 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is approximately $5 million, offset by current tax benefits of $1.4 million and amortization of EDIT of $3.6 million, for the nine months ended September 30, 2019, which results in no impact on earnings.

The decrease at NSTAR Electric was due to amortization of EDIT ($14.4 million), items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($2.7 million), and return to provision items ($1.3 million), partially offset by higher pre-tax earnings ($4.4 million) and higher state taxes ($1.6 million). The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is approximately $19.8 million, offset by a current tax benefit of $5.4 million and amortization of EDIT of $14.4 million, for the nine months ended September 30, 2019, which results in no impact on earnings.

~~The decrease at PSNH was due to lower state taxes ($3.2 million), amortization of EDIT ($3.1 million), lower pre-tax earnings ($1.8 million), and return to provision items ($1.1~~0.5 million), partially offset by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($~~1.3~~0.9 million), and an increase in share-based payment excess tax benefits ($1.8 million).

The ~~impact of the amortization of the EDIT regulatory liability, including the tax gross up portion, that reduced revenue is approximately $4.3 million,~~increase at PSNH was due primarily to higher pre-tax earnings ($5.3 million), higher state taxes ($1.2 million), and return to provision adjustments ($1.7 million), partially offset by an increase in share-based payment excess tax benefits ($0.6 million) and in items that impact our tax rate as a ~~current tax benefit~~result of ~~$1.2 million~~regulatory treatment (flow-through items) and ~~amortization of EDIT of $3.1 million for the nine months ended September 30, 2019, which results in no impact on earnings.~~permanent differences ($0.1 million).

EARNINGS SUMMARY

CL&P's earnings increased ~~$28.4~~$29.1 million for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the base distribution rate increases effective May 1, ~~2019~~2020 and May 1, ~~2018,~~2019, an increase in transmission earnings driven by a higher transmission rate base, and higher earnings from its capital tracker mechanism due to increased electric system improvements. The earnings increase was partially offset by higher operations and maintenance expense, higher depreciation expense, higher property and other tax expense, and higher interest expense.

NSTAR Electric's earnings increased $24.9 million for the nine months ended September 30, 2020, as compared to the same period in 2019, due primarily to the base distribution rate increase effective January 1, 2020 and an increase in transmission earnings driven by a higher transmission rate base. The earnings increase was partially offset by higher depreciation expense, higher interest expense, higher operations and maintenance expense, ~~lower non-service income from our benefit plans, higher depreciation expense~~ and higher property and other tax expense.

~~NSTAR Electric's~~PSNH's earnings increased ~~$33.0~~$17.9 million for the nine months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the base distribution rate increase effective January 1, 2019, lower non-tracked operations and maintenance expense, an increase in transmission earnings driven by a higher transmission rate base, and lower property tax expense. The earnings increase was partially offset by higher depreciation expense.

PSNH's earnings decreased $1.0 million for the nine months ended September 30, 2019, as compared to the same period in 2018, due primarily to the absence in 2019 of generation earnings as a result of the sale of its generation assets in 2018, a lower amount of carrying charges on storm costs approved for recovery in 2019, as compared to 2018, lower non-service income from our benefit plans, and higher operations and maintenance expense. The earnings decrease was partially offset by thetemporary base distribution rate increase effective July 1, 2019, and an increase in transmission earnings driven by a higher transmission rate base. The earnings increase was partially offset by the absence of the first quarter 2019 recognition of carrying charges on its 2013 through 2016 storm costs approved for recovery and higher operations and maintenance expense.

LIQUIDITY

Cash Flows: CL&P had cash flows provided by operating activities of ~~$531.5~~$399.2 million for the nine months ended September 30, ~~2019,~~2020, as compared to ~~$451.1~~$531.5 million in the same period of ~~2018.~~2019. The ~~increase~~decrease in operating cash flows was due primarily to the ~~absence in 2019~~timing of ~~approximately $120 million of storm restoration cost payments, the timing of~~cash collections on our accounts receivable and cash payments made in 2020 for storm restoration costs of approximately $56 million related to Tropical Storm Isaias.In addition, the timing of cash payments made on our accounts payable, ~~and a decrease of $17.2 million in pension contributions made in 2019. Partially offsetting these favorable impacts were higher income tax payments made in 2019 of $32.9 million, and~~ the timing of other working capital ~~items.~~items, and the timing of collections for regulatory tracking mechanisms, which includes the impact of the CL&P temporary rate suspension, contributed to the decrease in operating cash flows. Partially offsetting these unfavorable impacts were lower income tax payments made of $14.9 millionin the first nine months of 2020, as compared to the same period in 2019.

NSTAR Electric had cash flows provided by operating activities of ~~$586.9~~$502.6 million for the nine months ended September 30, ~~2019,~~2020, as compared to ~~$574.3~~$586.9 million in the same period of ~~2018.~~2019. The ~~increase~~decrease in operating cash flows was due primarily to ~~a decrease~~the timing of ~~approximately $77 million of major storm restoration cost payments,~~collections for regulatory tracking mechanisms primarily related to transmission costs, the timing of cash collections on our accounts receivable, the timing of cash payments made on our accounts payable, the timing of other working capital items, and a ~~decrease of $55.5~~$23.4 million increase in ~~pension and PBOP cash contributions, and lower~~ income tax payments made in 2020, as compared to the same period in 2019.

PSNH had cash flows provided by operating activities of $149.2 million for the nine months ended September 30, 2020, as compared to $202.8 million in the same period of 2019. The decrease in operating cash flows was due primarily to income tax payments of $23.0 million in the first nine months of 2020, as compared to income tax refunds received of $11.5 million in the same period in 2019, the timing of ~~$26.5 million. Partially offsetting these favorable impacts were~~REC inventories, the timing of collections for regulatory tracking mechanisms, and the timing of cash payments ~~made~~ on our accounts payable and ~~other working capital items.~~

~~PSNH had~~ cash flows provided by operating activities of $202.8 million for the nine months ended September 30, 2019, as compared to $217.7 million in the same period of 2018. The decrease in operating cash flows was due primarily to $15.4 million in pension contributions made in 2019 and the timing of cash payments madecollections on our accounts payable and other working capital items. Partially offsetting these unfavorable impacts were income tax refunds of $11.5 million in 2019, as compared to income tax payments of $14.9 million in the same period in 2018.receivable.

For further information on CL&P's, NSTAR Electric's and PSNH's liquidity and capital resources, see "Liquidity" and "Business Development and Capital Expenditures" included in this Management's Discussion and Analysis of Financial Condition and Results of Operations.

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 months ended September 30, ~~2019~~2020 and ~~2018~~2019 included in this combined Quarterly Report on Form 10-Q:


	For the Three Months Ended September 30,							For the Three Months Ended September 30,
(Millions of Dollars)	2019		2018		Increase/(Decrease)			2020		2019		Increase/(Decrease)
Operating Revenues	$	853.9	$	865.0	$	(11.1	)	$	994.3	$	853.9	$	140.4
Operating Expenses:
Purchased Power and Transmission	299.0		314.6		(15.6		)	399.1		299.0		100.1
Operations and Maintenance	135.1		128.5		6.6			147.5		135.1		12.4
Depreciation	76.3		72.0		4.3			80.6		76.3		4.3
Amortization of Regulatory Assets, Net	30.4		54.0		(23.6		)	36.4		30.4		6.0
Energy Efficiency Programs	40.1		30.2		9.9			41.8		40.1		1.7
Taxes Other Than Income Taxes	82.7		93.0		(10.3		)	97.7		82.7		15.0
Total Operating Expenses	663.6		692.3		(28.7		)	803.1		663.6		139.5
Operating Income	190.3		172.7		17.6			191.2		190.3		0.9
Interest Expense	39.5		37.6		1.9			38.4		39.5		(1.1		)
Other Income, Net	4.8		7.0		(2.2		)	5.9		4.8		1.1
Income Before Income Tax Expense	155.6		142.1		13.5			158.7		155.6		3.1
Income Tax Expense	43.9		41.8		2.1			38.6		43.9		(5.3		)
Net Income	$	111.7	$	100.3	$	11.4		$	120.1	$	111.7	$	8.4

Operating Revenues

Sales Volumes: CL&P's retail electric GWh sales volumes were ~~5,728~~5,798 and ~~6,153~~5,728 for the three months ended September 30, ~~2019~~2020 and ~~2018,~~2019, respectively, resulting in ~~a decrease~~an increase of ~~6.9~~1.2 percent. Fluctuations in retail electric sales volumes do not impact earnings due to its PURA-approved distribution revenue decoupling mechanism.

Operating Revenues: Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, ~~decreased $11.1~~increased $140.4 million for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018.~~2019.

Base Distribution Revenues: CL&P's distribution revenues increased ~~$13.8~~$8.9 million due primarily to the impact of its base distribution rate increase effective May 1, ~~2019 as a result of the PURA-approved rate case settlement agreement,~~2020, which includes recovery of storm costs and certain other items that do not impact earnings.

Tracked Revenues: Tracked revenues increased/(decreased) for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:

(Millions of Dollars)
Retail Tariff Tracked Revenues
Energy supply procurement $ (15.9 )
Retail transmission 1.7
Stranded cost recovery (4.4 )
Other distribution tracking mechanisms (5.0 )
Wholesale Market Sales Revenue 0.5

~~Revenues from CL&P's other distribution tracking mechanisms include higher earnings from its capital tracker mechanism effective July 1, 2018, due to increased electric system improvements.~~



(Millions of Dollars)
Retail Tariff Tracked Revenues
Energy supply procurement	$	(1.5	)
FMCC	51.4
Other distribution tracking mechanisms	22.6
Wholesale Market Sales Revenue	46.2

Transmission Revenues: Transmission revenues increased ~~$16.6~~$15.0 million due primarily to a higher transmission rate base as a result of continued investment in our transmission infrastructure.

Eliminations: Eliminations are primarily related to transmission revenues derived from ISO-NE regional transmission charges to the distribution business that recover the costs of the wholesale transmission business. The impact of eliminations decreased revenues by ~~$9.5~~$2.7 million.

Purchased Power and Transmission expense includes costs associated with purchasing electricity on behalf of CL&P's customers. These energy supply costs are recovered from customers in PURA-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power and Transmission expense ~~increased/(decreased)~~increased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:


(Millions of Dollars)
Purchased Power Costs	$	(6.2	)	$	105.6
Transmission Costs	0.1			(2.7		)
Eliminations	(9.5		)	(2.8		)
Total Purchased Power and Transmission	$	(15.6	)	$	100.1

The ~~decrease~~increase in purchased power costs was due primarily to athe new Millstone PPA energy purchases and higher average supply-related sales volumes, partially offset by lower average prices. The decrease ~~in both the price and volume of power procured on behalf of our customers. The increase~~ in transmission costs was due primarily to a ~~result of an increase~~decrease in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to ~~customers, and~~customers. This was partially offset by an increase in Local Network Service charges, which reflect the cost of transmission service provided by ~~Eversource~~CL&P over ~~our~~its local transmission ~~network. This was partially offset by a decrease~~network and an increase in costs billed by ISO-NE that support regional grid investments.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense ~~increased/(decreased)~~increased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the following:


(Millions of Dollars)
Base Electric Distribution (Non-Tracked Costs):
Employee-related expenses, including labor and benefits	$	(5.2	)
Operations-related expenses, including vegetation management, vehicles, and outside services	(5.2		)
Storm Restoration Costs	8.6			$	6.9
Shared corporate costs (including computer software depreciation at Eversource Service)				2.8
Other non-tracked operations and maintenance	(0.1		)	(1.0		)
Total Base Electric Distribution (Non-Tracked Costs)	(1.9		)	8.7
Total Tracked Costs	8.5			3.7
Total Operations and Maintenance	$	6.6		$	12.4

Depreciation expense increased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to a higher net plant in service ~~balances and the implementation of new depreciation rates effective with the 2018 CL&P distribution rate case settlement agreement.~~ balance.

Amortization of Regulatory Assets, Net expense includes the deferral of energy supply, ~~and~~ energy-related costs and other costs that are included in certain regulatory-approved cost tracking mechanisms, and the amortization of certain ~~costs.~~costs as those costs are collected in rates. This deferral adjusts ~~expenses~~expense to match the corresponding revenues. Energy supply and energy-related costs ~~which are the primary drivers of amortization,~~ are recovered from customers in rates and have no impact on earnings. Amortization of Regulatory Assets, Net ~~decreased~~increased at CL&P for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the deferral adjustment of energy supply and energy-related costs, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these ~~costs, partially offset by an increase in storm cost recovery.~~costs.

Energy Efficiency Programs expense includes costs of various state energy policy initiatives and expanded energy efficiency programs that are recovered from customers in rates, most of which have no impact on earnings. Energy Efficiency Programs expense increased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to ~~higher spending for~~the deferral adjustment, which reflects the actual costs of energy efficiency ~~programs.~~programs compared to the estimated amounts billed to customers and the timing of the recovery of energy efficiency costs.

Taxes Other Than Income Taxes ~~decreased~~increased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to higher gross earnings taxes, higher property taxes as a ~~decrease related to~~result of a higher utility plant balance, and the ~~remittance~~absence in 2020 of ~~energy efficiency funds to the State of Connecticut. Energy efficiency funds collected from customers after July 1, 2019 are no longer subject to remittance to the State of Connecticut.~~a use tax refund received in 2019.

Interest Expense increased at CL&P for the three months ended September 30, 2019, as compared to the same period in 2018, due primarily to an increase in interest expense on regulatory deferrals ($1.1 million) and an increase in interest expense on notes payable ($1.0 million), partially offset by an increase in AFUDC related to debt funds ($0.2 million).

~~Other Income, Net~~ decreased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to ~~market value changes related~~a decrease in interest on short-term notes payable ($1.1 million) and a decrease in interest expense on regulatory deferrals ($1.0 million), partially offset by higher interest on long-term debt ($1.1 million).

Other Income, Net increased for the three months ended September 30, 2020, as compared to the ~~deferred compensation plans~~same period in 2019, due primarily to investment income in 2020 compared to investment losses in 2019 driven by market volatility ($~~1.5~~2.1 million) ~~and~~, partially offset by a decrease related to pension, SERP and PBOP non-service income components ($~~0.3~~0.8 million).

Income Tax Expense ~~increased~~decreased for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the absence in 2020 of an increase in valuation allowance ($9.3 million), partially offset by higher pre-tax earnings ($0.7 million), higher state taxes ($0.8 million), return to provision adjustments ($1.1 million), and by items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($~~3.4~~1.4 million)~~, higher pretax income ($2.8 million) and state taxes ($1 million), partially offset by amortization of EDIT ($2.2 million) and return to provision items ($2.9 million)~~. The impact of the amortization of the EDIT regulatory liability, including the tax gross up portion that reduced revenue is approximately $3 million, offset by a current tax benefit of $0.8 million, and amortization of EDIT of $2.2 million, for the three months ended September 30, 2019, which results in no impact on earnings.

EARNINGS SUMMARY

CL&P's earnings increased ~~$11.4~~$8.4 million for the three months ended September 30, ~~2019,~~2020, as compared to the same period in ~~2018,~~2019, due primarily to the base distribution rate increase effective May 1, ~~2019,~~2020, an increase in transmission earnings driven by a higher transmission rate base, ~~lower non-tracked operations and maintenance expense~~ and higher earnings from its capital tracker ~~mechanism.~~mechanism due to increased electric system improvements. The earnings increase was partially offset by higher operations and maintenance expense, higher property and other tax expense, and higher depreciation expense.


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.

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 natural 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, ~~2019,~~2020, our regulated companies held collateral ~~in the form of letters~~(letters of credit or cash) of ~~$10.5~~$5.0 million from counterparties related to our standard service contracts. As of September 30, ~~2019,~~2020, Eversource had ~~$19.2~~$29.6 million of cash posted with ISO-NE related to energy 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 ~~2018~~2019 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 ~~2018~~2019 Form 10-K.


ITEM 4.	CONTROLS AND PROCEDURES

Management, on behalf of Eversource, CL&P, NSTAR Electric and PSNH, evaluated the design and operation of the disclosure controls and procedures as of September 30, ~~2019~~2020 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 and PSNH are effective to ensure that information required to be disclosed by us in reports filed under the Securities Exchange Act of 1934 (i) is recorded, processed, summarized, and reported within the time periods specified in SEC rules and regulations and (ii) is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosures.

There have been no changes in internal controls over financial reporting for Eversource, CL&P, NSTAR Electric and PSNH during the quarter ended September 30, ~~2019~~2020 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.

PART II. OTHER INFORMATION


ITEM 1.	LEGAL PROCEEDINGS

We are parties to various legal proceedings. We have disclosed certain legal proceedings in Part I, Item 3, "Legal Proceedings," and elsewhere in our ~~2018~~2019 Form 10-K. These disclosures are incorporated herein by reference.

~~PSNH Merrimack Generation Facility Civil Suit~~: On March 4, 2019, the Sierra Club and the Conservation Law Foundation (the “Plaintiffs”) filed a citizens suit under the federal Clean Water Act against PSNH and a non-affiliated party that currently owns the Merrimack generation facility (the “Defendants”) in the U.S. District Court for the District of New Hampshire (the “Court”). With respect to PSNH, the suit alleges that there was a failure to completely report certain monitoring data to the EPA and other agencies as required by the National Pollutant Discharge Elimination System Permit at the Merrimack generation facility for events occurring after January 3, 2014, but prior to PSNH’s sale of the Merrimack generation facility on January 10, 2018. The Plaintiffs seek injunctive relief and imposition of maximum civil penalties assessable against PSNH as well as attorneys’ fees and costs. At a hearing on August 15, 2019, the Court was informed that the maximum civil penalties against PSNH are $195 million.

At this time, PSNH cannot predict the outcome of this matter or the impact on its financial statements. PSNH believes this action is without merit and intends to defend it vigorously; however, an adverse outcome in this suit could have a material impact on our results of operations, financial condition and liquidity.

~~Yankee Companies v. U.S. Department of Energy~~: As previously disclosed, on May 22, 2017, each of the Yankee Companies filed subsequent lawsuits against the DOE in the Court of Federal Claims. The Yankee Companies sought monetary damages totaling $104.4 million for CYAPC, YAEC and MYAPC, resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2013 to 2016 (“DOE Phase IV”). On February 21, 2019, the Yankee Companies received a partial summary judgment and partial final judgment in their favor for the undisputed amount of monetary damages of $103.2 million. The court awarded CYAPC, YAEC and MYAPC damages of $40.7 million, $28.1 million and $34.4 million, respectively. The DOE did not appeal the court's judgment and the decision became final on April 23, 2019. On June 12, 2019, the court accepted an offer of judgment in the amount of $0.5 million to settle the disputed amount of approximately $1 million in Phase IV contested damages. The Yankee Companies received the $0.5 million payment in July 2019. For a further discussion of the ~~Yankee Companies v. U.S. Department of Energy,~~ ~~see Part I, Item 3, “Legal Proceedings” of our 2018 Form 10-K.~~

~~Other than as set forth above, there~~There have been no ~~additional~~ material legal proceedings identified and no ~~further~~ material changes with regard to the legal proceedings previously disclosed in our ~~2018~~2019 Form 10-K.


ITEM 1A.	RISK FACTORS

We are subject to a variety of significant risks in addition to the matters set forth under our forward-looking statements section 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 ~~2018~~2019 Form 10-K, which risk factors are incorporated herein by reference. These risk factors should be considered carefully in evaluating our risk profile. ~~There~~The following risk factor should be read in conjunction with the risk factors described in the 2019 Form 10-K.

The global pandemic of the novel coronavirus (COVID-19) has resulted in widespread disruption to the many systems and processes of daily life, as well as the overall economic market and outlook, which could cause various unfavorable impacts to our customers, vendors, employees, regulators, and operations and could adversely affect our financial position, results of operations and cash flows.

We are responding to COVID-19 by taking steps to mitigate the potential risks to Eversource posed by its spread. We provide a critical service to our customers, which means it is paramount that we keep our employees who operate our businesses safe and minimize unnecessary risk of exposure to COVID-19. We have updated and implemented our company-wide pandemic plan to address specific aspects of the COVID-19 pandemic. This plan guides our emergency response, business continuity, and the precautionary measures we are taking on behalf of employees and our customers. As part of our pandemic plan, we are taking extra precautions to mitigate an adverse material impact to the following risk factors that we believe could continue to be impacted by COVID-19:

•

Cybersecurity attacks: During the COVID-19 timeframe, we had initially seen an increase in the volume of perimeter scanning for vulnerabilities, but have recently seen a return of pre-COVID-19 volume of perimeter scanning. This scanning can be leveraged to compromise a system. We have also seen increased business email compromises of vendors to gain access to their email systems to be used in more advanced phishing attacks. We had seen increased phishing attempts targeted at our employees by outside parties to gain control of our systems and network. We continue to implement strong cybersecurity measures and have increased the education of our employees and contractors to ensure that our systems remain functional in order to both serve our operational needs with a remote workforce and to ensure uninterrupted service to our customers. Our incident response team works with compromised vendors to assist them in improving their security posture. We also continuously review and update our response plans to include responding to an event while in a remote work environment.

•

Access to, or cost of, capital resources: We utilize the commercial paper market extensively for our short-term borrowing needs. At the onset of the pandemic in the United States, liquidity in the commercial paper credit market began to deteriorate rapidly. However, federal legislative actions, including actions taken by the Federal Reserve, have provided sufficient liquidity and stabilization of the credit markets. We continue to monitor the ability for us to access the global capital and credit markets; however, if we are unable to access these markets, then our financial condition may be adversely affected.

•

Actions of regulators: We continue to work closely with our state regulatory commissions and consumer advocates on customer assistance measures, including payment plan options in order to mitigate the impact on customer rates in the future, as well as financial hardship and arrearage management programs for those customers who are unable to pay their utility bills. We developed these long-term solutions for customers in order to help minimize the extent of the impact of COVID-19 on customer receivable balances and customers’ affordability in light of the current financial impact they may experience. We believe that we have in place, or are developing, successful mechanisms with our state regulatory commissions to recover our incremental costs associated with COVID-19, while balancing the impact on our customers’ bills and our operating cash flows, however our financial condition may be adversely affected depending on the outcome of planned proceedings before our state regulatory commissions.

•

Timing of strategic development opportunities: The successful execution of our timeline for developing our offshore wind projects is based on several factors, including state and federal siting and permitting approvals. Between March 2020 and June 2020, COVID-19-related work restrictions prohibited work in New York and within New York jurisdictional waters. Those restrictions delayed offshore site investigations, and onshore environmental and geotechnical surveys, which could adversely impact our project siting and permit filing timelines. On September 25, 2020, the state of New York Administrative Law Judge granted a change to the start of the South Fork Wind evidentiary hearing schedule to December 2, 2020, due to continuing settlement conferences amongst the parties. Although we are unable to predict the impact of those delays on our offshore wind projects at this time, we are currently developing mitigation plans to address permitting delays due to COVID-19 restrictions on our offshore wind projects. Similarly, we are unable to assess the potential impact that a reintroduction of these work restrictions in response to a future increase in COVID-19 infections would have on our projects.


•	Suppliers and Vendors: We have instituted measures to ensure our supply chain remains open to us; however, there could be global shortages that will impact our maintenance, capital programs, and storm response that we currently cannot anticipate.

•

Loss of key personnel: We continue to adjust our pandemic plan to address various scenarios including reduced workforce levels and limited mutual aid in the event of a significant storm event. We have implemented remote work arrangements for our workforce by enabling nearly half of our employees to work from home and taking extra precautions for our field-based employees. We have taken significant safety measures to ensure adequate social distancing for our field crews to safely provide essential services to our customers. We have also adopted protocols to ensure the safety and health of those employees who work onsite in critical facilities. We continue to monitor COVID-19 developments affecting our workforce and will take additional precautions that we determine are necessary in order to mitigate the impacts. Although to date our workforce continues to be able to safely and reliably deliver our critical services to customers, we are unable to predict the extent of the impact of COVID-19 on our employees.

•

Impact to Benefit Plans: As of September 30, 2020, under the Pension Protection Act, the funded status of our pension plan was approximately 103 percent. The pension and PBOP plans' funded status is highly dependent on benefit plan asset returns, interest rates, and discount rates, all of which could be materially impacted by an extended economic slowdown. Should these financial metrics be negatively impacted by COVID-19 as of December 31, 2020, it could result in the underperformance of our pension and PBOP plan investments, an increase in pension and PBOP obligations and employee benefit plan costs, and in a minimum pension funding requirement due by March 31, 2022 for the 2021 Plan year. We continue to monitor federal legislative pension developments that could provide additional pension funding relief.

We are currently unable to estimate the potential impact of COVID-19 to our financial position, results of operations and cash flows.

Other than as set forth above, there have been no additional risk factors identified and no material changes with regard to the risk factors previously disclosed in our ~~2018~~2019 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 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, 2019 —
$ —
—
—
August 1 - August 31, 2019 —
—
—
—
September 1 - September 30, 2019 2,185
85.75
—
—
Total 2,185
$ 85.75
—
—



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, 2020	—	$	—	—	—
August 1 - August 31, 2020	—	—		—	—
September 1 - September 30, 2020	2,277	83.53		—	—
Total	2,277	$	83.53	—	—


ITEM 6.	EXHIBITS

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



	Exhibit No.	Description

	Listing of Exhibits (Eversource)
*	4.1	Thirteenth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of August 1, 2020, relating to $300 million aggregate principal amount of Senior Notes, Series Q, Due 2025 and $600 million aggregate principal amount of Senior Notes, Series R, Due 2030 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed August 20, 2020, File No. 001-05324)

*	4.2	Twelfth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company N.A., as Trustee, dated as of January 1, 2020, establishing the terms of the additional $300 million aggregate principal amount of Senior Notes, Series P, Due 2050 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed January 16, 2020, File No. 001-05324)

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

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

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

	Listing of Exhibits (CL&P)
*	~~4.1~~	~~Supplemental Indenture (2017 Series A Bonds) between CL&P and Deutsche Bank Trust Company Americas, as Trustee, dated as of September 1, 2019 (Exhibit 4.1, CL&P Current Report on Form 8-K filed on September 23, 2019, File No. 000-00404~~)

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

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

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

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

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

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

	Listing of Exhibits (PSNH)
*	4.1	Twenty-Third Supplemental Indenture establishing the terms of the Bonds, dated as of August 1, 2020, between the Company and U.S. Bank National Association, as Trustee, relating to $150 million of 2.40% First Mortgage Bonds, Series U, due 2050 (Exhibit 4.1, Public Service Company of New Hampshire Current Report on Form 8-K filed August 31, 2020, File No. 001-06392)

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

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

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

	Listing of Exhibits (Eversource, CL&P, NSTAR Electric, PSNH)
	101.INS	Inline XBRL Instance Document - the instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document



	101.SCH		Inline XBRL Taxonomy Extension Schema

	101.CAL		Inline XBRL Taxonomy Extension Calculation

	101.DEF		Inline XBRL Taxonomy Extension Definition



	101.LAB		Inline XBRL Taxonomy Extension Labels

	101.PRE		Inline XBRL Taxonomy Extension Presentation

	104		The cover page from the Quarterly Report on Form 10-Q for the quarter ended September 30, ~~2019,~~2020, formatted in Inline XBRL

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 ~~7, 2019~~6, 2020	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE



	THE CONNECTICUT LIGHT AND POWER COMPANY

November ~~7, 2019~~6, 2020	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE



	NSTAR ELECTRIC COMPANY

November ~~7, 2019~~6, 2020	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE



	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE

November ~~7, 2019~~6, 2020	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

7074



	Total Provision for Uncollectible Accounts				Provision for Uncollectible Hardship Accounts
(Millions of Dollars)	As of September 30, 2019		As of December 31, 2018		As of September 30, 2019		As of December 31, 2018
Eversource	$	225.5	$	212.7	$	146.5	$	131.5
CL&P	94.1		88.0		77.8		71.9
NSTAR Electric	80.7		74.5		49.4		42.5
PSNH	10.6		11.1		—		—



(Millions of Dollars)	Issue Date	Issuance/(Repayment)			Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P:
4.00% 2018 Series A First Mortgage Bonds ⁽¹⁾	April 2019	$	300.0		April 2048	Paid short-term borrowings that were used to pay long-term debt that matured on February 1, 2019 and fund capital expenditures and working capital
3.20% 2017 Series A First Mortgage Bonds ⁽²⁾	September 2019	200.0			March 2027	Paid short-term borrowings and fund capital expenditures and working capital
5.50% 2009 Series A First Mortgage Bonds	February 2009	(250.0		)	February 2019	Paid at maturity on February 1, 2019
NSTAR Electric:
3.25% 2019 Debentures	May 2019	400.0			May 2029	Paid short-term borrowings that were used to fund investments in eligible green expenditures
PSNH:
3.60% 2019 Series T First Mortgage Bonds	June 2019	300.0			July 2049	Paid long-term debt due to mature in December 2019, paid short-term borrowings and fund capital expenditures and working capital
Other:
NSTAR Gas 3.74% Series Q First Mortgage Bonds	July 2019	75.0			August 2049	Paid short-term borrowings and fund capital expenditures and working capital
Yankee Gas 2.23% Series P First Mortgage Bonds	September 2019	100.0			October 2024	Paid long-term debt due to mature in November 2019, paid short-term borrowings and fund capital expenditures and working capital
Yankee Gas 3.30% Series Q First Mortgage Bonds	September 2019	100.0			October 2049	Paid long-term debt due to mature in November 2019, paid short-term borrowings and fund capital expenditures and working capital



		As of September 30, 2019
(Millions of Dollars)	Balance Sheet Classification	Eversource		CL&P		NSTAR Electric		PSNH
Operating Leases:
Operating Lease Right-of-use-Assets, Net	Other Long-Term Assets	$	52.3	$	0.9	$	24.2	$	0.4
Operating Lease Liabilities
Operating Lease Liabilities - Current Portion	Other Current Liabilities	$	8.9	$	0.5	$	0.6	$	—
Operating Lease Liabilities - Long-Term	Other Long-Term Liabilities	43.4		0.4		23.6		0.4
Total Operating Lease Liabilities		$	52.3	$	0.9	$	24.2	$	0.4
Finance Leases:
Finance Lease Right-of-use-Assets, Net	Property, Plant and Equipment, Net	$	8.8	$	2.2	$	3.4	$	0.9
Finance Lease Liabilities
Finance Lease Liabilities - Current Portion	Other Current Liabilities	$	2.3	$	1.6	$	—	$	0.1
Finance Lease Liabilities - Long-Term	Other Long-Term Liabilities	8.7		1.8		4.4		0.8
Total Finance Lease Liabilities		$	11.0	$	3.4	$	4.4	$	0.9



For the Nine Months Ended September 30, 2019
Cash Paid for Amounts Included in the Measurement of Lease Liabilities:
Operating Cash Flows from Operating Leases	$	8.7	$	0.3	$	1.2	$	0.1
Operating Cash Flows from Finance Leases	1.0		0.4		0.4		—
Financing Cash Flows from Finance Leases	1.5		1.0		—		0.1
Supplemental Non-Cash Information on Lease Liabilities:
Right-of-use-Assets Obtained in Exchange for New Operating Lease Liabilities	2.6		1.0		—		0.2
Right-of-use-Assets Obtained in Exchange for New Finance Lease Liabilities	1.3		—		—		—



	Operating Leases								Finance Leases
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
October 1, 2019 through December 31, 2019	$	2.6	$	0.1	$	0.3	$	—	$	0.9	$	0.5	$	0.1	$	—
Year Ending December 31,
2020	10.1		0.5		1.6		0.1		3.4		2.0		0.5		0.1
2021	8.9		0.2		1.6		0.1		2.9		1.5		0.5		0.1
2022	7.4		—		1.6		0.1		1.5		—		0.6		0.1
2023	4.9		—		1.6		—		0.7		—		0.6		0.1
2024	2.8		—		1.6		—		0.7		—		0.6		0.1
Thereafter	28.9		0.1		28.7		0.2		13.3		—		12.8		0.5
Future lease payments	65.6		0.9		37.0		0.5		23.4		4.0		15.7		1.0
Less amount representing interest	13.3		—		12.8		0.1		12.4		0.6		11.3		0.1
Present value of future minimum lease payments	$	52.3	$	0.9	$	24.2	$	0.4	$	11.0	$	3.4	$	4.4	$	0.9



Operating Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	11.5	$	1.5	$	7.2	$	0.5
2020	9.8		1.4		6.0		0.4
2021	8.7		1.2		5.3		0.4
2022	7.2		1.1		4.4		0.4
2023	4.7		0.5		3.1		0.2
Thereafter	32.7		0.2		29.5		0.3
Future minimum lease payments	$	74.6	$	5.9	$	55.5	$	2.2



Capital Leases (Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH
2019	$	3.4	$	2.0	$	0.5	$	0.1
2020	3.4		2.0		0.5		0.1
2021	2.9		1.5		0.5		0.1
2022	1.5		—		0.6		0.1
2023	0.7		—		0.6		0.1
Thereafter	13.9		—		13.4		0.5
Future minimum lease payments	25.8		5.5		16.1		1.0
Less amount representing interest	13.8		1.0		12.4		0.1
Present value of future minimum lease payments	$	12.0	$	4.5	$	3.7	$	0.9