10-Q

	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	March 31, 2023
	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: 001-05324

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: 000-00404

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: 001-02301

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: 001-06392

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 April 30, 2023
Eversource Energy Common Shares, $5.00 par value	348,841,840	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 Instruction 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, 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
EGMA	Eversource Gas Company of Massachusetts
Yankee Gas	Yankee Gas Services Company
Aquarion	Aquarion Company and its subsidiaries
HEEC	Harbor Electric Energy Company, a wholly-owned subsidiary of NSTAR Electric
Eversource Service	Eversource Energy Service Company
North East Offshore	North East Offshore, LLC, an offshore wind business being developed jointly by Eversource and Denmark-based Ørsted
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, NSTAR Gas and EGMA, Aquarion’s water distribution businesses, and the solar power facilities of NSTAR Electric
Regulators and Government Agencies:
BOEM	U.S. Bureau of Ocean Energy Management
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
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
CfD	Contract for Differences
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 2022 Form 10-K	The Eversource Energy and Subsidiaries 2022 combined Annual Report on Form 10-K as filed with the SEC
Fitch	Fitch Ratings, Inc.

i

FMCC	Federally Mandated Congestion Charge
GAAP	Accounting principles generally accepted in the United States of America
GWh	Gigawatt-Hours
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)
LNG	Liquefied natural gas
LPG	Liquefied petroleum gas
LRS	Supplier of last resort service
MG	Million gallons
MGP	Manufactured Gas Plant
MMBtu	Million British thermal units
MMcf	Million cubic feet
Moody's	Moody's Investors Services, Inc.
MW	Megawatt
MWh	Megawatt-Hours
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
Pension Plan	Single uniform noncontributory defined benefit retirement plan
PPA	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
SERP	Supplemental Executive Retirement Plans and non-qualified defined benefit retirement plans
SS	Standard service
UI	The United Illuminating Company
VIE	Variable Interest Entity

ii

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	4
	The Connecticut Light and Power Company (Unaudited)
	Condensed Balance Sheets	5
	Condensed Statements of Income	6
	Condensed Statements of Comprehensive Income	6
	Condensed Statements of Common Stockholder's Equity	7
	Condensed Statements of Cash Flows	8
	NSTAR Electric Company and Subsidiary (Unaudited)
	Condensed Consolidated Balance Sheets	9
	Condensed Consolidated Statements of Income	10
	Condensed Consolidated Statements of Comprehensive Income	10
	Condensed Consolidated Statements of Common Stockholder's Equity	11
	Condensed Consolidated Statements of Cash Flows	12
	Public Service Company of New Hampshire and Subsidiaries (Unaudited)
	Condensed Consolidated Balance Sheets	13
	Condensed Consolidated Statements of Income	14
	Condensed Consolidated Statements of Comprehensive Income	14
	Condensed Consolidated Statements of Common Stockholder's Equity	15
	Condensed Consolidated Statements of Cash Flows	16
	Combined Notes to Condensed Financial Statements (Unaudited)	17
ITEM 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations
	Eversource Energy and Subsidiaries	35
	The Connecticut Light and Power Company, NSTAR Electric Company and Subsidiary, and Public Service Company of New Hampshire and Subsidiaries	49
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	54
ITEM 4.	Controls and Procedures	54
PART II – OTHER INFORMATION
ITEM 1.	Legal Proceedings	55
ITEM 1A.	Risk Factors	55
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	55
ITEM 6.	Exhibits	56
SIGNATURES		57

iii

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(Thousands of Dollars)	As of March 31, 2023		As of December 31, 2022
ASSETS
Current Assets:
Cash	$	35,975	$	47,597
Cash Equivalents	—		327,006
Receivables, Net (net of allowance for uncollectible accounts of $535,114    and $486,297 as of March 31, 2023 and December 31, 2022, respectively)	1,660,076		1,517,138
Unbilled Revenues	216,715		238,968
Materials, Supplies, Natural Gas and REC Inventory	423,343		374,395
Regulatory Assets	1,332,028		1,335,491
Prepayments and Other Current Assets	468,292		382,603
Total Current Assets	4,136,429		4,223,198
Property, Plant and Equipment, Net	36,744,855		36,112,820
Deferred Debits and Other Assets:
Regulatory Assets	4,407,875		4,242,794
Goodwill	4,522,632		4,522,632
Investments in Unconsolidated Affiliates	2,302,880		2,176,080
Prepaid Pension and PBOP	1,097,814		1,045,524
Marketable Securities	332,050		366,508
Other Long-Term Assets	560,632		541,344
Total Deferred Debits and Other Assets	13,223,883		12,894,882
Total Assets	$	54,105,167	$	53,230,900
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	1,195,500	$	1,442,200
Long-Term Debt – Current Portion	1,615,461		1,320,129
Rate Reduction Bonds – Current Portion	43,210		43,210
Accounts Payable	1,821,911		2,113,905
Regulatory Liabilities	650,538		890,786
Other Current Liabilities	1,078,421		989,053
Total Current Liabilities	6,405,041		6,799,283
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	5,239,443		5,067,902
Regulatory Liabilities	3,974,374		3,930,305
Derivative Liabilities	124,281		143,929
Asset Retirement Obligations	500,695		502,713
Accrued Pension, SERP and PBOP	120,200		135,473
Other Long-Term Liabilities	884,717		888,081
Total Deferred Credits and Other Liabilities	10,843,710		10,668,403
Long-Term Debt	20,562,588		19,723,994
Rate Reduction Bonds	388,887		410,492
Noncontrolling Interest – Preferred Stock of Subsidiaries	155,570		155,570
Common Shareholders' Equity:
Common Shares	1,799,920		1,799,920
Capital Surplus, Paid In	8,412,085		8,401,731
Retained Earnings	5,782,958		5,527,153
Accumulated Other Comprehensive Loss	(36,191)		(39,421)
Treasury Stock	(209,401)		(216,225)
Common Shareholders' Equity	15,749,371		15,473,158
Commitments and Contingencies (Note 9)
Total Liabilities and Capitalization	$	54,105,167	$	53,230,900

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

1

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars, Except Share Information)	2023		2022
Operating Revenues	$	3,795,643	$	3,471,310
Operating Expenses:
Purchased Power, Purchased Natural Gas and Transmission	1,903,246		1,389,696
Operations and Maintenance	454,562		472,433
Depreciation	312,955		289,330
Amortization	(76,059)		236,948
Energy Efficiency Programs	222,952		199,484
Taxes Other Than Income Taxes	228,414		220,364
Total Operating Expenses	3,046,070		2,808,255
Operating Income	749,573		663,055
Interest Expense	194,543		153,245
Other Income, Net	88,981		71,561
Income Before Income Tax Expense	644,011		581,371
Income Tax Expense	150,972		136,045
Net Income	493,039		445,326
Net Income Attributable to Noncontrolling Interests	1,880		1,880
Net Income Attributable to Common Shareholders	$	491,159	$	443,446
Basic and Diluted Earnings Per Common Share	$	1.41	$	1.28
Weighted Average Common Shares Outstanding:
Basic	349,217,147		345,156,346
Diluted	349,612,013		345,661,133

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 March 31,
(Thousands of Dollars)	2023		2022
Net Income	$	493,039	$	445,326
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	5		5
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,254		(817)
Changes in Funded Status of Pension, SERP and PBOP Benefit Plans	1,971		1,516
Other Comprehensive Income, Net of Tax	3,230		704
Comprehensive Income Attributable to Noncontrolling Interests	(1,880)		(1,880)
Comprehensive Income Attributable to Common Shareholders	$	494,389	$	444,150

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

2

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

(Unaudited)

	For the Three Months Ended March 31, 2023
	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
Balance as of January 1, 2023	348,443,855	$	1,799,920	$	8,401,731	$	5,527,153	$	(39,421)	$	(216,225)	$	15,473,158
Net Income						493,039						493,039
Dividends on Common Shares - $0.675 Per Share						(235,354)						(235,354)
Dividends on Preferred Stock						(1,880)						(1,880)
Long-Term Incentive Plan Activity				(13,141)								(13,141)
Issuance of Treasury Shares	364,227			23,495						6,824		30,319
Other Comprehensive Income								3,230				3,230
Balance as of March 31, 2023	348,808,082	$	1,799,920	$	8,412,085	$	5,782,958	$	(36,191)	$	(209,401)	$	15,749,371

	For the Three Months Ended March 31, 2022
	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
Balance as of January 1, 2022	344,403,196	$	1,789,092	$	8,098,514	$	5,005,391	$	(42,275)	$	(250,878)	$	14,599,844
Net Income						445,326						445,326
Dividends on Common Shares - $0.6375 Per Share						(219,768)						(219,768)
Dividends on Preferred Stock						(1,880)						(1,880)
Long-Term Incentive Plan Activity				(16,538)								(16,538)
Issuance of Treasury Shares	447,076			20,642						8,360		29,002
Other Comprehensive Income								704				704
Balance as of March 31, 2022	344,850,272	$	1,789,092	$	8,102,618	$	5,229,069	$	(41,571)	$	(242,518)	$	14,836,690

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

3

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars)	2023		2022
Operating Activities:
Net Income	$	493,039	$	445,326
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	312,955		289,330
Deferred Income Taxes	149,197		67,557
Uncollectible Expense	22,821		17,135
Pension, SERP and PBOP Income, Net	(24,563)		(40,642)
Pension Contributions	(1,100)		(26,100)
Regulatory Under Recoveries, Net	(158,964)		(107,767)
Customer Credits at CL&P related to PURA Settlement Agreement and Storm     Performance Penalty	—		(58,412)
Amortization	(76,059)		236,948
Cost of Removal Expenditures	(70,514)		(61,660)
Other	(54,486)		(21,409)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(225,609)		(291,723)
Taxes Receivable/Accrued, Net	284		56,519
Accounts Payable	(258,476)		(68,909)
Other Current Assets and Liabilities, Net	(39,368)		(64,253)
Net Cash Flows Provided by Operating Activities	69,157		371,940
Investing Activities:
Investments in Property, Plant and Equipment	(977,144)		(764,594)
Proceeds from Sales of Marketable Securities	64,307		90,409
Purchases of Marketable Securities	(56,508)		(76,182)
Investments in Unconsolidated Affiliates	(87,845)		(113,856)
Other Investing Activities	5,640		5,976
Net Cash Flows Used in Investing Activities	(1,051,550)		(858,247)
Financing Activities:
Cash Dividends on Common Shares	(229,405)		(213,890)
Cash Dividends on Preferred Stock	(1,880)		(1,880)
(Decrease)/Increase in Notes Payable	(246,700)		163,350
Repayment of Rate Reduction Bonds	(21,605)		(21,605)
Issuance of Long-Term Debt	1,550,000		1,300,000
Retirement of Long-Term Debt	(400,000)		(770,000)
Other Financing Activities	(27,002)		(26,087)
Net Cash Flows Provided by Financing Activities	623,408		429,888
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(358,985)		(56,419)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	521,752		221,008
Cash and Restricted Cash - End of Period	$	162,767	$	164,589

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

4

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED BALANCE SHEETS

(Unaudited)

(Thousands of Dollars)	As of March 31, 2023		As of December 31, 2022
ASSETS
Current Assets:
Cash	$	9,340	$	11,312
Receivables, Net (net of allowance for uncollectible accounts of $253,376 and    $225,320 as of March 31, 2023 and December 31, 2022, respectively)	633,048		612,052
Accounts Receivable from Affiliated Companies	69,095		46,439
Unbilled Revenues	54,048		59,363
Materials and Supplies	103,987		88,157
Taxes Receivable	26,723		65,785
Regulatory Assets	356,468		314,089
Prepayments and Other Current Assets	93,078		62,524
Total Current Assets	1,345,787		1,259,721
Property, Plant and Equipment, Net	11,630,278		11,467,024
Deferred Debits and Other Assets:
Regulatory Assets	1,639,960		1,593,693
Prepaid Pension	155,856		147,914
Other Long-Term Assets	302,817		290,444
Total Deferred Debits and Other Assets	2,098,633		2,032,051
Total Assets	$	15,074,698	$	14,758,796
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	318,000	$	—
Accounts Payable	622,024		710,500
Accounts Payable to Affiliated Companies	141,792		136,277
Regulatory Liabilities	124,640		336,048
Derivative Liabilities	85,105		81,588
Other Current Liabilities	205,692		163,875
Total Current Liabilities	1,497,253		1,428,288
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,740,504		1,640,034
Regulatory Liabilities	1,277,281		1,263,396
Derivative Liabilities	124,281		143,929
Other Long-Term Liabilities	160,104		166,081
Total Deferred Credits and Other Liabilities	3,302,170		3,213,440
Long-Term Debt	4,310,233		4,216,488
Preferred Stock Not Subject to Mandatory Redemption	116,200		116,200
Common Stockholder's Equity:
Common Stock	60,352		60,352
Capital Surplus, Paid In	3,260,765		3,260,765
Retained Earnings	2,527,520		2,463,094
Accumulated Other Comprehensive Income	205		169
Common Stockholder's Equity	5,848,842		5,784,380
Commitments and Contingencies (Note 9)
Total Liabilities and Capitalization	$	15,074,698	$	14,758,796

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

5

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF INCOME

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars)	2023		2022
Operating Revenues	$	1,338,905	$	1,285,831
Operating Expenses:
Purchased Power and Transmission	850,564		523,463
Operations and Maintenance	160,316		157,061
Depreciation	92,237		87,265
Amortization of Regulatory (Liabilities)/Assets, Net	(122,315)		169,749
Energy Efficiency Programs	32,646		35,397
Taxes Other Than Income Taxes	101,584		90,373
Total Operating Expenses	1,115,032		1,063,308
Operating Income	223,873		222,523
Interest Expense	45,201		40,586
Other Income, Net	14,937		19,564
Income Before Income Tax Expense	193,609		201,501
Income Tax Expense	45,193		48,524
Net Income	$	148,416	$	152,977

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

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars)	2023		2022
Net Income	$	148,416	$	152,977
Other Comprehensive Income/(Loss), Net of Tax:
Qualified Cash Flow Hedging Instruments	(7)		(7)
Changes in Unrealized Gains/(Losses) on Marketable Securities	43		(28)
Other Comprehensive Income/(Loss), Net of Tax	36		(35)
Comprehensive Income	$	148,452	$	152,942

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

6

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)

	For the Three Months Ended March 31, 2023
	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
Balance as of January 1, 2023	6,035,205	$	60,352	$	3,260,765	$	2,463,094	$	169	$	5,784,380
Net Income						148,416				148,416
Dividends on Preferred Stock						(1,390)				(1,390)
Dividends on Common Stock						(82,600)				(82,600)
Other Comprehensive Income								36		36
Balance as of March 31, 2023	6,035,205	$	60,352	$	3,260,765	$	2,527,520	$	205	$	5,848,842

	For the Three Months Ended March 31, 2022
	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
Balance as of January 1, 2022	6,035,205	$	60,352	$	3,010,765	$	2,228,133	$	251	$	5,299,501
Net Income						152,977				152,977
Dividends on Preferred Stock						(1,390)				(1,390)
Dividends on Common Stock						(73,100)				(73,100)
Capital Contributions from Eversource Parent				100,000						100,000
Other Comprehensive Loss								(35)		(35)
Balance as of March 31, 2022	6,035,205	$	60,352	$	3,110,765	$	2,306,620	$	216	$	5,477,953

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

7

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars)	2023		2022
Operating Activities:
Net Income	$	148,416	$	152,977
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by   Operating Activities:
Depreciation	92,237		87,265
Deferred Income Taxes	94,267		19,627
Uncollectible Expense	3,876		3,776
Pension, SERP, and PBOP Income, Net	(4,461)		(7,330)
Regulatory Under Recoveries, Net	(110,114)		(162,474)
Customer Credits related to PURA Settlement Agreement and Storm Performance Penalty	—		(58,412)
Amortization of Regulatory (Liabilities)/Assets, Net	(122,315)		169,749
Cost of Removal Expenditures	(13,011)		(16,684)
Other	(13,964)		(9,357)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(76,482)		(125,429)
Taxes Receivable/Accrued, Net	52,261		67,708
Accounts Payable	(110,926)		38,010
Other Current Assets and Liabilities, Net	(13,412)		(24,143)
Net Cash Flows (Used in)/Provided by Operating Activities	(73,628)		135,283
Investing Activities:
Investments in Property, Plant and Equipment	(255,905)		(205,343)
Other Investing Activities	126		346
Net Cash Flows Used in Investing Activities	(255,779)		(204,997)
Financing Activities:
Cash Dividends on Common Stock	(82,600)		(73,100)
Cash Dividends on Preferred Stock	(1,390)		(1,390)
Capital Contributions from Eversource Parent	—		100,000
Issuance of Long-Term Debt	500,000		—
Retirement of Long-Term Debt	(400,000)		—
Increase in Notes Payable to Eversource Parent	318,000		—
Other Financing Activities	(6,521)		—
Net Cash Flows Provided by Financing Activities	327,489		25,510
Net Decrease in Cash and Restricted Cash	(1,918)		(44,204)
Cash and Restricted Cash - Beginning of Period	20,327		74,788
Cash and Restricted Cash - End of Period	$	18,409	$	30,584

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

8

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(Thousands of Dollars)	As of March 31, 2023		As of December 31, 2022
ASSETS
Current Assets:
Cash	$	618	$	738
Cash Equivalents	—		327,006
Receivables, Net (net of allowance for uncollectible accounts of $94,556 and    $94,958 as of March 31, 2023 and December 31, 2022, respectively)	500,985		453,371
Accounts Receivable from Affiliated Companies	59,062		35,196
Unbilled Revenues	43,091		39,680
Materials, Supplies and REC Inventory	190,301		138,352
Regulatory Assets	559,758		492,759
Prepayments and Other Current Assets	62,149		71,276
Total Current Assets	1,415,964		1,558,378
Property, Plant and Equipment, Net	11,819,012		11,626,968
Deferred Debits and Other Assets:
Regulatory Assets	1,263,534		1,221,619
Prepaid Pension and PBOP	596,214		576,809
Other Long-Term Assets	118,185		111,846
Total Deferred Debits and Other Assets	1,977,933		1,910,274
Total Assets	$	15,212,909	$	15,095,620
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable	$	147,500	$	—
Long-Term Debt – Current Portion	80,000		80,000
Accounts Payable	514,504		559,676
Accounts Payable to Affiliated Companies	164,953		108,907
Obligations to Third Party Suppliers	156,717		142,628
Renewable Portfolio Standards Compliance Obligations	157,580		120,239
Regulatory Liabilities	375,047		373,221
Other Current Liabilities	80,908		83,925
Total Current Liabilities	1,677,209		1,468,596
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,758,232		1,700,875
Regulatory Liabilities	1,557,614		1,548,081
Other Long-Term Liabilities	292,953		289,313
Total Deferred Credits and Other Liabilities	3,608,799		3,538,269
Long-Term Debt	4,346,024		4,345,085
Preferred Stock Not Subject to Mandatory Redemption	43,000		43,000
Common Stockholder's Equity:
Common Stock	—		—
Capital Surplus, Paid In	2,810,242		2,778,942
Retained Earnings	2,727,367		2,921,444
Accumulated Other Comprehensive Income	268		284
Common Stockholder's Equity	5,537,877		5,700,670
Commitments and Contingencies (Note 9)
Total Liabilities and Capitalization	$	15,212,909	$	15,095,620

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

9

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars)	2023		2022
Operating Revenues	$	956,283	$	863,176
Operating Expenses:
Purchased Power and Transmission	360,925		313,748
Operations and Maintenance	166,083		164,862
Depreciation	90,430		89,033
Amortization of Regulatory Assets, Net	22,785		29,345
Energy Efficiency Programs	86,217		80,232
Taxes Other Than Income Taxes	53,510		59,774
Total Operating Expenses	779,950		736,994
Operating Income	176,333		126,182
Interest Expense	44,865		38,222
Other Income, Net	39,873		29,231
Income Before Income Tax Expense	171,341		117,191
Income Tax Expense	37,528		24,452
Net Income	$	133,813	$	92,739

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 March 31,
(Thousands of Dollars)	2023		2022
Net Income	$	133,813	$	92,739
Other Comprehensive Loss, Net of Tax:
Changes in Funded Status of SERP Benefit Plan	(33)		(44)
Qualified Cash Flow Hedging Instruments	5		5
Changes in Unrealized Gains/(Losses) on Marketable Securities	12		(8)
Other Comprehensive Loss, Net of Tax	(16)		(47)
Comprehensive Income	$	133,797	$	92,692

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

10

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)

	For the Three Months Ended March 31, 2023
	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
Balance as of January 1, 2023	200	$	—	$	2,778,942	$	2,921,444	$	284	$	5,700,670
Net Income						133,813				133,813
Dividends on Preferred Stock						(490)				(490)
Dividends on Common Stock						(327,400)				(327,400)
Capital Contributions from Eversource Parent				31,300						31,300
Other Comprehensive Loss								(16)		(16)
Balance as of March 31, 2023	200	$	—	$	2,810,242	$	2,727,367	$	268	$	5,537,877

	For the Three Months Ended March 31, 2022
	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
Balance as of January 1, 2022	200	$	—	$	2,253,942	$	2,718,576	$	501	$	4,973,019
Net Income						92,739				92,739
Dividends on Preferred Stock						(490)				(490)
Dividends on Common Stock						(71,900)				(71,900)
Other Comprehensive Loss								(47)		(47)
Balance as of March 31, 2022	200	$	—	$	2,253,942	$	2,738,925	$	454	$	4,993,321

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

11

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars)	2023		2022
Operating Activities:
Net Income	$	133,813	$	92,739
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	90,430		89,033
Deferred Income Taxes	44,403		26,857
Uncollectible Expense	4,697		4,662
Pension, SERP and PBOP Income, Net	(9,886)		(13,742)
Pension Contributions	—		(5,000)
Regulatory Under Recoveries, Net	(58,000)		(10,813)
Amortization of Regulatory Assets, Net	22,785		29,345
Cost of Removal Expenditures	(12,893)		(12,852)
Other	(9,921)		(5,531)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(90,684)		2,051
Taxes Receivable/Accrued, Net	11,977		45,299
Accounts Payable	20,249		(55,743)
Other Current Assets and Liabilities, Net	(6,185)		3,559
Net Cash Flows Provided by Operating Activities	140,785		189,864
Investing Activities:
Investments in Property, Plant and Equipment	(318,673)		(234,120)
Other Investing Activities	35		96
Net Cash Flows Used in Investing Activities	(318,638)		(234,024)
Financing Activities:
Cash Dividends on Common Stock	(327,400)		(71,900)
Cash Dividends on Preferred Stock	(490)		(490)
Capital Contributions from Eversource Parent	31,300		—
Increase in Notes Payable to Eversource Parent	—		4,000
Increase in Notes Payable	147,500		112,500
Other Financing Activities	5		15
Net Cash Flows (Used in)/Provided by Financing Activities	(149,085)		44,125
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(326,938)		(35)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	345,293		18,179
Cash and Restricted Cash - End of Period	$	18,355	$	18,144

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

12

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

(Thousands of Dollars)	As of March 31, 2023		As of December 31, 2022
ASSETS
Current Assets:
Cash	$	88	$	136
Receivables, Net (net of allowance for uncollectible accounts of $33,505 and $29,236    as of March 31, 2023 and December 31, 2022, respectively)	167,960		173,337
Accounts Receivable from Affiliated Companies	25,270		8,193
Unbilled Revenues	67,266		72,713
Taxes Receivable	48,173		27,978
Materials, Supplies and REC Inventory	43,492		34,521
Regulatory Assets	140,912		102,240
Special Deposits	19,469		33,140
Prepayments and Other Current Assets	6,869		13,297
Total Current Assets	519,499		465,555
Property, Plant and Equipment, Net	4,147,985		4,060,224
Deferred Debits and Other Assets:
Regulatory Assets	697,568		593,974
Prepaid Pension	70,892		66,384
Other Long-Term Assets	15,183		16,517
Total Deferred Debits and Other Assets	783,643		676,875
Total Assets	$	5,451,127	$	5,202,654
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Notes Payable to Eversource Parent	$	121,100	$	173,300
Long-Term Debt – Current Portion	325,000		29,668
Rate Reduction Bonds – Current Portion	43,210		43,210
Accounts Payable	301,547		291,556
Accounts Payable to Affiliated Companies	51,985		36,231
Regulatory Liabilities	86,569		161,963
Other Current Liabilities	62,784		59,616
Total Current Liabilities	992,195		795,544
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	625,374		562,802
Regulatory Liabilities	390,290		391,628
Other Long-Term Liabilities	37,418		37,087
Total Deferred Credits and Other Liabilities	1,053,082		991,517
Long-Term Debt	1,134,407		1,134,914
Rate Reduction Bonds	388,887		410,492
Common Stockholder's Equity:
Common Stock	—		—
Capital Surplus, Paid In	1,298,134		1,298,134
Retained Earnings	584,422		572,126
Accumulated Other Comprehensive Loss	—		(73)
Common Stockholder's Equity	1,882,556		1,870,187
Commitments and Contingencies (Note 9)
Total Liabilities and Capitalization	$	5,451,127	$	5,202,654

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

13

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars)	2023		2022
Operating Revenues	$	420,155	$	339,427
Operating Expenses:
Purchased Power and Transmission	226,685		125,844
Operations and Maintenance	67,796		59,573
Depreciation	34,088		31,253
Amortization of Regulatory (Liabilities)/Assets, Net	(5,317)		26,834
Energy Efficiency Programs	10,226		8,718
Taxes Other Than Income Taxes	22,105		22,785
Total Operating Expenses	355,583		275,007
Operating Income	64,572		64,420
Interest Expense	17,542		13,645
Other Income, Net	5,717		7,509
Income Before Income Tax Expense	52,747		58,284
Income Tax Expense	12,451		12,698
Net Income	$	40,296	$	45,586

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 March 31,
(Thousands of Dollars)	2023		2022
Net Income	$	40,296	$	45,586
Other Comprehensive Income/(Loss), Net of Tax:
Changes in Unrealized Gains/(Losses) on Marketable Securities	73		(48)
Other Comprehensive Income/(Loss), Net of Tax	73		(48)
Comprehensive Income	$	40,369	$	45,538

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

14

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)

	For the Three Months Ended March 31, 2023
	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
Balance as of January 1, 2023	301	$	—	$	1,298,134	$	572,126	$	(73)	$	1,870,187
Net Income						40,296				40,296
Dividends on Common Stock						(28,000)				(28,000)
Other Comprehensive Income								73		73
Balance as of March 31, 2023	301	$	—	$	1,298,134	$	584,422	$	—	$	1,882,556

	For the Three Months Ended March 31, 2022
	Common Stock			Capital Surplus, Paid In		Retained Earnings		Accumulated Other Comprehensive Income/(Loss)		Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	Stock	Amount
Balance as of January 1, 2022	301	$	—	$	1,088,134	$	504,556	$	23	$	1,592,713
Net Income						45,586				45,586
Dividends on Common Stock						(26,000)				(26,000)
Other Comprehensive Loss								(48)		(48)
Balance as of March 31, 2022	301	$	—	$	1,088,134	$	524,142	$	(25)	$	1,612,251

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

15

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	For the Three Months Ended March 31,
(Thousands of Dollars)	2023		2022
Operating Activities:
Net Income	$	40,296	$	45,586
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by   Operating Activities:
Depreciation	34,088		31,253
Deferred Income Taxes	62,924		7,480
Uncollectible Expense	5,060		2,496
Pension, SERP and PBOP Income, Net	(2,552)		(3,997)
Regulatory Under Recoveries, Net	(175,865)		(32,186)
Amortization of Regulatory (Liabilities)/Assets, Net	(5,317)		26,834
Cost of Removal Expenditures	(4,508)		(7,131)
Other	1,711		(4,631)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(21,230)		(25,972)
Taxes Receivable/Accrued, Net	(20,195)		8,067
Accounts Payable	10,265		9,389
Other Current Assets and Liabilities, Net	2,462		895
Net Cash Flows (Used In)/Provided by Operating Activities	(72,861)		58,083
Investing Activities:
Investments in Property, Plant and Equipment	(133,890)		(107,916)
Other Investing Activities	216		593
Net Cash Flows Used in Investing Activities	(133,674)		(107,323)
Financing Activities:
Cash Dividends on Common Stock	(28,000)		(26,000)
Issuance of Long-Term Debt	300,000		—
Repayment of Rate Reduction Bonds	(21,605)		(21,605)
(Decrease)/Increase in Notes Payable to Eversource Parent	(52,200)		85,800
Other Financing Activities	(5,460)		(23)
Net Cash Flows Provided by Financing Activities	192,735		38,172
Net Decrease in Cash and Restricted Cash	(13,800)		(11,068)
Cash and Restricted Cash - Beginning of Period	36,812		35,126
Cash and Restricted Cash - End of Period	$	23,012	$	24,058

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

16

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, NSTAR Gas and EGMA (natural gas utilities), and Aquarion (water utilities). Eversource provides energy delivery and/or water service to approximately 4.4 million electric, natural gas and water customers through twelve regulated utilities in Connecticut, Massachusetts and New Hampshire.

The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries.  Intercompany transactions have been eliminated in consolidation.  The accompanying unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P 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 2022 Form 10-K, which was filed with the SEC on February 15, 2023. 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 March 31, 2023 and December 31, 2022, and the results of operations, comprehensive income, common shareholders' equity and cash flows for the three months ended March 31, 2023 and 2022. The results of operations, comprehensive income and cash flows for the three months ended March 31, 2023 and 2022 are not necessarily indicative of the results expected for a full year.  

CYAPC and YAEC are inactive regional nuclear power companies engaged in the long-term storage of their spent nuclear fuel. Eversource consolidates the operations of 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.

Certain reclassifications of prior period data were made in the accompanying financial statements to conform to the current period presentation.

B.    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). The current expected credit loss (CECL) model is applied to receivables for purposes of calculating the allowance for uncollectible accounts. This 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.

17

The allowance for uncollectible accounts is determined based upon a variety of judgments and factors, including an aging-based quantitative assessment that applies an estimated uncollectible percentage to each receivable aging category.  Factors in determining credit loss include historical collection, write-off experience, analysis of delinquency statistics, and management's assessment of collectability from customers, including current economic conditions, customer payment trends, the impact on customer bills because of energy usage trends and changes in rates, flexible payment plans and financial hardship arrearage management programs being offered to customers, reasonable forecasts, and expectations of future collectability and collection efforts. Management continuously assesses the collectability of receivables and adjusts estimates based on actual experience and future expectations based on economic conditions, 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 allowance for uncollectible accounts when the customer accounts are no longer in service and these balances are deemed to be uncollectible. Management concluded that the reserve balance as of March 31, 2023 adequately reflected the collection risk and net realizable value for its receivables.

As of both March 31, 2023 and December 31, 2022, the total amount incurred as a result of COVID-19 included in the allowance for uncollectible accounts was $50.9 million at Eversource, $16.0 million at CL&P, and $4.1 million at NSTAR Electric. At our Connecticut and Massachusetts utilities, the 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 future rates. No COVID-19 related uncollectible amounts were deferred at PSNH as a result of a July 2021 NHPUC order. Based on the status of our COVID-19 regulatory dockets, policies and practices in the jurisdictions in which we operate, we believe the state regulatory commissions in Connecticut and Massachusetts will allow us to recover our incremental uncollectible customer receivable costs associated with COVID-19.

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, NSTAR Gas and EGMA 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. Management uses a higher credit risk profile for this pool of trade receivables as compared to non-hardship receivables. The allowance for uncollectible hardship accounts is included in the total uncollectible allowance balance.

The total allowance for uncollectible accounts is included in Receivables, Net on the balance sheets. The activity in the allowance for uncollectible accounts by portfolio segment as of March 31st is as follows:

	Eversource						CL&P						NSTAR Electric						PSNH
(Millions of Dollars)	Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Total Allowance
Three Months Ended 2023
Beginning Balance	$	284.4	$	201.9	$	486.3	$	188.9	$	36.4	$	225.3	$	43.7	$	51.3	$	95.0	$	29.2
Uncollectible Expense	—		22.8		22.8		—		3.9		3.9		—		4.7		4.7		5.1
Uncollectible Costs Deferred (1)	43.7		14.3		58.0		34.3		2.7		37.0		(1.3)		5.4		4.1		1.2
Write-Offs	(9.7)		(26.3)		(36.0)		(7.3)		(7.0)		(14.3)		(0.4)		(10.3)		(10.7)		(2.2)
Recoveries Collected	0.3		3.7		4.0		0.3		1.2		1.5		—		1.5		1.5		0.2
Ending Balance	$	318.7	$	216.4	$	535.1	$	216.2	$	37.2	$	253.4	$	42.0	$	52.6	$	94.6	$	33.5

Three Months Ended 2022
Beginning Balance	$	226.1	$	191.3	$	417.4	$	144.6	$	36.7	$	181.3	$	43.3	$	53.7	$	97.0	$	24.3
Uncollectible Expense	—		17.1		17.1		—		3.8		3.8		—		4.7		4.7		2.5
Uncollectible Costs Deferred (1)	0.9		14.8		15.7		(4.0)		(2.1)		(6.1)		(3.3)		5.4		2.1		1.0
Write-Offs	(2.3)		(22.0)		(24.3)		(1.1)		(0.5)		(1.6)		(0.3)		(10.6)		(10.9)		(1.8)
Recoveries Collected	0.8		5.5		6.3		0.6		2.5		3.1		—		1.9		1.9		0.2
Ending Balance	$	225.5	$	206.7	$	432.2	$	140.1	$	40.4	$	180.5	$	39.7	$	55.1	$	94.8	$	26.2

(1) These expected credit losses are deferred as regulatory costs on the balance sheets, as these amounts are ultimately recovered in rates. Amounts include uncollectible costs for hardship accounts and other customer receivables, including uncollectible amounts related to uncollectible energy supply costs and COVID-19. The increase in the allowance for uncollectible hardship accounts in 2023 at Eversource and CL&P primarily relates to increased customer enrollment in disconnection prevention programs in Connecticut.

18

C.    Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" (normal) and to 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, equity method investments, AROs, and in the valuation of business combinations and asset acquisitions. The fair value measurement guidance was also applied in estimating the 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. The 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 10, "Fair Value of Financial Instruments," to the financial statements.

D.    Other Income, Net

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

	For the Three Months Ended
	March 31, 2023								March 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Pension, SERP and PBOP Non-Service    Income Components, Net of Deferred Portion	$	34.8	$	9.5	$	14.7	$	4.2	$	54.3	$	15.9	$	21.0	$	6.6
AFUDC Equity	15.5		4.1		9.5		0.7		9.9		2.8		4.9		0.4
Equity in Earnings of Unconsolidated Affiliates	3.8		—		0.1		—		0.4		—		—		—
Investment (Loss)/Income	(1.7)		(0.6)		(0.5)		(0.1)		(0.2)		(0.4)		(0.3)		0.2
Interest Income	23.1		1.9		16.0		0.9		6.7		1.3		3.5		0.3
Other	13.5		—		0.1		—		0.5		—		0.1		—
Total Other Income, Net	$	89.0	$	14.9	$	39.9	$	5.7	$	71.6	$	19.6	$	29.2	$	7.5

E.    Investments in Unconsolidated Affiliates

Investments in entities that are not consolidated are included in long-term assets on the balance sheets and earnings impacts from these equity investments are included in Other Income, Net on the statements of income.  Eversource's investments included the following:

			Investment Balance
(Millions of Dollars)	Ownership Interest		As of March 31, 2023		As of December 31, 2022
Offshore Wind Business - North East Offshore	50	%	$	2,159.2	$	1,947.1
Natural Gas Pipeline - Algonquin Gas Transmission, LLC	15	%	117.5		118.8
Renewable Energy Investment Fund	90	%	—		84.1
Other	various		26.2		26.1
Total Investments in Unconsolidated Affiliates			$	2,302.9	$	2,176.1

Offshore Wind Business: Eversource’s offshore wind business includes a 50 percent ownership interest in North East Offshore, which holds PPAs and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind projects, as well as an undeveloped offshore lease area. The offshore wind investment includes capital expenditures for the three offshore wind projects, as well as capitalized costs related to future development, acquisition costs of offshore lease areas, and capitalized interest.

19

On May 4, 2022, Eversource announced that it had initiated a strategic review of its offshore wind investment portfolio. As part of that review, Eversource is exploring strategic alternatives that could result in a potential sale of all, or part, of its 50 percent interest in its offshore wind partnership with Ørsted. Eversource continues to work with interested parties through this ongoing process and expects to complete this review in the second quarter of 2023. Eversource’s strategic review of its offshore wind investment does not impact the presentation of the March 31, 2023 financial statements.

Equity method investments are assessed for impairment when conditions exist that indicate that the fair value of the investment is less than book value. Eversource continually monitors and evaluates its equity method investments to determine if there are indicators of an other-than-temporary impairment. Eversource believes that the fair market value of its offshore wind investment is greater than the carrying value based upon management’s expectation for future cash flows arising from the sale of all, or part, of its investment. There are uncertainties in a sale process, and there could be changes in market conditions that would impact Eversource’s ability to sell this investment or the value it would receive for these assets. In the event that the strategic review does not result in the sale of the offshore wind business or that a sale of the offshore wind business is significantly delayed or at a lower than expected value from these changes in market conditions driven by unfavorable developments, such as scheduling or permitting delays, increases in actual costs and cost estimates, changes to tax laws impacting the project’s ability to monetize tax attributes, higher interest rates, and increases in the discount rate, it could result in Eversource having to evaluate whether or not its investment is impaired. Any resulting impairment charge could have a material adverse effect on Eversource’s financial position and results of operations.

Liquidation of Renewable Energy Investment Fund: On March 21, 2023, Eversource’s equity method investment in a renewable energy investment fund was liquidated by the fund’s general partner in accordance with the partnership agreement. Proceeds received from the liquidation were $123.4 million and are included in Investments in Unconsolidated Affiliates within investing activities on the statement of cash flows. Additional amounts in escrow as of March 31, 2023 resulting from the liquidation were received in the second quarter of 2023. A portion of the proceeds were used to make a charitable contribution to the Eversource Energy Foundation (a related party) of $20.0 million in the first quarter of 2023. The liquidation benefit and charitable contribution are included in Other Income, Net on the statement of income.

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
(Millions of Dollars)	March 31, 2023		March 31, 2022
Eversource	$	55.0	$	48.6
CL&P	43.1		37.8

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

G.    Supplemental Cash Flow Information

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

(Millions of Dollars)	As of March 31, 2023		As of March 31, 2022
Eversource	$	400.8	$	385.6
CL&P	101.9		102.1
NSTAR Electric	117.4		85.8
PSNH	54.6		49.5

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 March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Cash and Cash Equivalents as reported on the Balance Sheets	$	36.0	$	9.3	$	0.6	$	0.1	$	374.6	$	11.3	$	327.7	$	0.1
Restricted cash included in:
Special Deposits	89.0		8.9		17.8		19.5		102.2		8.8		17.5		33.1
Marketable Securities	17.9		0.2		—		0.2		25.4		0.2		0.1		0.4
Other Long-Term Assets	19.9		—		—		3.2		19.6		—		—		3.2
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows	$	162.8	$	18.4	$	18.4	$	23.0	$	521.8	$	20.3	$	345.3	$	36.8

Special Deposits represent cash collections related to the PSNH RRB customer charges that are held in trust, required ISO-NE cash deposits, cash held in escrow accounts, 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 obligations.

20

Restricted cash includes an Energy Relief Fund for energy efficiency and clean energy measures in the Merrimack Valley and an additional energy efficiency program established under the terms of the EGMA 2020 settlement agreement. This restricted cash included $20.0 million recorded as short-term in Special Deposits as of both March 31, 2023 and December 31, 2022, and $16.7 million and $15.9 million recorded in Other Long-Term Assets on the balance sheets as of March 31, 2023 and December 31, 2022, respectively.

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, 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 and the regulatory assets that have been recorded.  If management were to determine that it could no longer apply the accounting guidance applicable to rate-regulated enterprises, or if management could not conclude it is probable that costs would be recovered from customers in future rates, the applicable 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 March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Storm Costs, Net	$	1,658.7	$	889.2	$	564.9	$	204.6	$	1,379.1	$	799.3	$	484.4	$	95.4
Regulatory Tracking Mechanisms	1,028.7		228.2		432.4		122.8		1,075.3		216.8		391.5		73.7
Benefit Costs	910.3		155.6		294.4		56.1		921.7		156.7		299.5		56.6
Income Taxes, Net	856.1		492.9		118.1		13.1		853.3		491.1		115.6		16.0
Securitized Stranded Costs	424.9		—		—		424.9		435.7		—		—		435.7
Goodwill-related	276.7		—		237.6		—		281.0		—		241.2		—
Derivative Liabilities	168.8		168.8		—		—		181.8		181.8		—		—
Asset Retirement Obligations	129.2		36.5		68.0		4.5		127.9		35.9		68.2		4.4
Other Regulatory Assets	286.5		25.3		107.9		12.5		322.5		26.2		114.0		14.4
Total Regulatory Assets	5,739.9		1,996.5		1,823.3		838.5		5,578.3		1,907.8		1,714.4		696.2
Less:  Current Portion	1,332.0		356.5		559.8		140.9		1,335.5		314.1		492.8		102.2
Total Long-Term Regulatory Assets	$	4,407.9	$	1,640.0	$	1,263.5	$	697.6	$	4,242.8	$	1,593.7	$	1,221.6	$	594.0

Regulatory Costs in Long-Term Assets:  Eversource's regulated companies had $223.6 million (including $146.5 million for CL&P, $19.7 million for NSTAR Electric and $1.1 million for PSNH) and $210.8 million (including $135.9 million for CL&P, $19.8 million for NSTAR Electric and $1.0 million for PSNH) of additional regulatory costs as of March 31, 2023 and December 31, 2022, 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 both March 31, 2023 and December 31, 2022, these regulatory costs included incremental COVID-19 related non-tracked uncollectible expense deferred of $29.8 million at Eversource, $11.8 million at CL&P, and $2.2 million at NSTAR Electric.

21

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

	As of March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
EDIT due to Tax Cuts and Jobs Act of 2017	$	2,601.8	$	980.0	$	933.9	$	346.1	$	2,619.3	$	983.6	$	944.3	$	348.6
Cost of Removal	705.4		144.2		412.9		20.2		670.6		130.8		405.3		14.7
Regulatory Tracking Mechanisms	653.6		145.0		341.6		73.2		890.8		361.0		336.1		155.0
Deferred Portion of Non-Service Income    Components of Pension, SERP and PBOP	291.4		38.3		148.5		30.8		270.9		34.5		139.7		28.8
AFUDC - Transmission	103.8		49.8		54.0		—		98.2		48.2		50.0		—
Benefit Costs	49.2		0.6		27.1		—		55.4		0.7		31.4		—
Other Regulatory Liabilities	219.7		44.0		14.6		6.6		215.9		40.6		14.5		6.5
Total Regulatory Liabilities	4,624.9		1,401.9		1,932.6		476.9		4,821.1		1,599.4		1,921.3		553.6
Less:  Current Portion	650.5		124.6		375.0		86.6		890.8		336.0		373.2		162.0
Total Long-Term Regulatory Liabilities	$	3,974.4	$	1,277.3	$	1,557.6	$	390.3	$	3,930.3	$	1,263.4	$	1,548.1	$	391.6

3.    PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

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

Eversource	As of March 31, 2023		As of December 31, 2022
(Millions of Dollars)
Distribution - Electric	$	18,618.6	$	18,326.2
Distribution - Natural Gas	7,562.8		7,443.8
Transmission - Electric	13,884.0		13,709.3
Distribution - Water	2,122.5		2,112.6
Solar	200.8		200.8
Utility	42,388.7		41,792.7
Other (1)	1,791.7		1,738.1
Property, Plant and Equipment, Gross	44,180.4		43,530.8
Less:  Accumulated Depreciation
Utility	(9,317.7)		(9,167.4)
Other	(744.7)		(706.1)
Total Accumulated Depreciation	(10,062.4)		(9,873.5)
Property, Plant and Equipment, Net	34,118.0		33,657.3
Construction Work in Progress	2,626.9		2,455.5
Total Property, Plant and Equipment, Net	$	36,744.9	$	36,112.8

	As of March 31, 2023						As of December 31, 2022
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Distribution - Electric	$	7,510.8	$	8,516.7	$	2,631.4	$	7,370.1	$	8,410.0	$	2,586.4
Transmission - Electric	6,235.2		5,382.8		2,267.6		6,165.1		5,333.8		2,212.0
Solar	—		200.8		—		—		200.8		—
Property, Plant and Equipment, Gross	13,746.0		14,100.3		4,899.0		13,535.2		13,944.6		4,798.4
Less:  Accumulated Depreciation	(2,610.4)		(3,429.3)		(940.0)		(2,567.1)		(3,381.2)		(912.3)
Property, Plant and Equipment, Net	11,135.6		10,671.0		3,959.0		10,968.1		10,563.4		3,886.1
Construction Work in Progress	494.7		1,148.0		189.0		498.9		1,063.6		174.1
Total Property, Plant and Equipment, Net	$	11,630.3	$	11,819.0	$	4,148.0	$	11,467.0	$	11,627.0	$	4,060.2

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

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 electricity or natural gas is delivered.

22

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 March 31, 2023						As of December 31, 2022
CL&P (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
Current Derivative Assets	Level 3	$	17.0	$	(0.5)	$	16.5	$	16.3	$	(0.5)	$	15.8
Long-Term Derivative Assets	Level 3	24.9		(0.8)		24.1		28.8		(0.9)		27.9
Current Derivative Liabilities	Level 3	(85.1)		—		(85.1)		(81.6)		—		(81.6)
Long-Term Derivative Liabilities	Level 3	(124.3)		—		(124.3)		(143.9)		—		(143.9)

    

(1)    Amounts represent derivative assets and liabilities that Eversource elected to record net on the balance sheets.  These amounts are subject to master netting agreements or similar agreements for which the right of offset exists.

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 March 31, 2023 and December 31, 2022 were 674 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. 

Fair Value Measurements of Derivative Instruments

The fair value of derivative contracts classified as Level 3 utilizes both significant observable and unobservable inputs.  The fair value is modeled using income techniques, such as discounted cash flow valuations adjusted for assumptions related to exit price.  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.  Significant observable inputs for valuations of these contracts include energy-related product prices in future years for which quoted prices in an active market exist. 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.  Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy-related products, and accounting requirements.

The following is a summary of the significant unobservable inputs utilized in the valuations of the derivative contracts classified as Level 3:

	As of March 31, 2023								As of December 31, 2022
CL&P	Range				Average			Period Covered	Range				Average			Period Covered
Forward Reserve Prices	$	0.44	—	$0.50	$	0.47	per kW-Month	2023 - 2024	$	0.44	—	$0.50	$	0.47	per kW-Month	2023 - 2024

Exit price premiums of 2.3 percent through 6.6 percent, or a weighted average of 5.5 percent, are also Level 3 significant unobservable inputs 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.  

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 March 31,
(Millions of Dollars)	2023		2022
Derivatives, Net:
Fair Value as of Beginning of Period	$	(181.8)	$	(249.2)
Net Realized/Unrealized (Losses)/Gains Included in Regulatory Assets	(1.9)		6.2
Settlements	14.9		13.6
Fair Value as of End of Period	$	(168.8)	$	(229.4)

23

5.    MARKETABLE SECURITIES

Eversource holds marketable securities that are primarily used to fund certain non-qualified executive benefits.  The trusts that hold these marketable securities are not subject to regulatory oversight by state or federal agencies.  Eversource’s marketable securities also include the CYAPC and YAEC legally restricted trusts that each hold equity and available-for-sale debt securities to fund the spent nuclear fuel removal obligations of their nuclear fuel storage facilities. Equity and available-for-sale debt marketable securities are recorded at fair value, with the current portion recorded in Prepayments and Other Current Assets and the long-term portion recorded in Marketable Securities on the balance sheets.

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 March 31, 2023 and December 31, 2022 was $19.6 million and $20.0 million, respectively.  For the three months ended March 31, 2023 and 2022, there were unrealized gains of $0.8 million and unrealized losses of $4.4 million, respectively, recorded in Other Income, Net related to these equity securities.

Eversource's equity securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of $170.9 million and $170.1 million as of March 31, 2023 and December 31, 2022, 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 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:

	As of March 31, 2023								As of December 31, 2022
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
Debt Securities	$	196.5	$	0.2	$	(14.8)	$	181.9	$	201.6	$	0.1	$	(16.2)	$	185.5

Unrealized gains and losses on available-for-sale debt securities held in Eversource's non-qualified executive benefit trust are recorded in Accumulated Other Comprehensive Income, excluding amounts related to credit losses or losses on securities intended to be sold, which are recorded in Other Income, Net. There were $1.2 million of unrealized losses recorded on securities intended to be sold for the three months ended March 31, 2023 that were included in Other Income, Net. There have been no credit losses for the three months ended March 31, 2023 and 2022, and no allowance for credit losses as of March 31, 2023. Factors considered in determining whether a credit loss exists include adverse conditions specifically affecting the issuer, the payment history, ratings and rating changes of the security, and the severity of the impairment.  For 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.

Eversource's debt securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts in the amounts of $161.2 million and $163.2 million as of March 31, 2023 and December 31, 2022, respectively. Unrealized gains and losses for available-for-sale debt securities included in the CYAPC and YAEC spent nuclear fuel trusts are subject to regulatory accounting treatment and are recorded in Marketable Securities with the corresponding offset to long-term liabilities on the balance sheets, with no impact on the statements of income. Pre-tax unrealized gains and losses as of March 31, 2023 and December 31, 2022 primarily relate to the debt securities included in CYAPC's and YAEC's spent nuclear fuel trusts.

As of March 31, 2023, the contractual maturities of available-for-sale debt securities were as follows:

 

Eversource (Millions of Dollars)	Amortized Cost		Fair Value
Less than one year (1)	$	39.8	$	38.9
One to five years	42.5		41.1
Six to ten years	35.6		32.8
Greater than ten years	78.6		69.1
Total Debt Securities	$	196.5	$	181.9

(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. Amounts also include securities in Eversource’s non-qualified executive benefit trust, which are intended to be sold in 2023.

Realized Gains and Losses:  Realized gains and losses are recorded in Other Income, Net for Eversource's benefit trust and are offset in 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.

24

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 March 31, 2023		As of December 31, 2022
Level 1:
Mutual Funds and Equities	$	190.5	$	190.1
Money Market Funds	17.9		25.4
Total Level 1	$	208.4	$	215.5
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury)	$	91.5	$	82.3
Corporate Debt Securities	44.2		46.1
Asset-Backed Debt Securities	8.5		8.6
Municipal Bonds	9.2		12.7
Other Fixed Income Securities	10.6		10.4
Total Level 2	$	164.0	$	160.1
Total Marketable Securities	$	372.4	$	375.6

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: Eversource parent has a $2.00 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas, EGMA and Aquarion Water Company of Connecticut are parties to a five-year $2.00 billion revolving credit facility, which terminates on October 15, 2027. This revolving credit facility serves to backstop Eversource parent's $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 October 15, 2027, and 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
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
(Millions of Dollars)
Eversource Parent Commercial Paper Program	$	1,048.0	$	1,442.2	$	952.0	$	557.8	5.22	%	4.63	%
NSTAR Electric Commercial Paper Program	147.5		—		502.5		650.0		4.77	%	—	%

There were no borrowings outstanding on the revolving credit facilities as of March 31, 2023 or December 31, 2022.

CL&P and PSNH have uncommitted line of credit agreements totaling $450 million and $300 million, respectively, which will expire on May 12, 2023. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of March 31, 2023.

Amounts outstanding under the commercial paper programs are included in Notes Payable and 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.

Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. 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 March 31, 2023, there were intercompany loans from Eversource parent to CL&P of $318.0 million and to PSNH of $121.1 million. As of December 31, 2022, there were intercompany loans from Eversource parent to PSNH of $173.3 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time.

Sources and Uses of Cash: The Company expects the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with 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.

25

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

(Millions of Dollars)	Interest Rate		Issuance/(Repayment)		Issue Date or Repayment Date	Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P 2023 Series A First Mortgage Bonds	5.25	%	$	500.0	January 2023	January 2053	Repaid 2013 Series A Bonds at maturity and short-term debt, and paid capital expenditures and working capital
CL&P 2013 Series A First Mortgage Bonds	2.50	%	(400.0)		January 2023	January 2023	Paid at maturity
PSNH Series W First Mortgage Bonds	5.15	%	300.0		January 2023	January 2053	Repaid short-term debt, paid capital expenditures and working capital
Eversource Parent Series Z Senior Notes	5.45	%	750.0		March 2023	March 2028	Repaid Series F Senior Notes at maturity and short-term debt
Eversource Parent Series F Senior Notes	2.80	%	(450.0)		May 2023	May 2023	Paid at maturity

7.    RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

Rate Reduction Bonds: In May 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 are paid semi-annually, beginning on February 1, 2019. The RRBs were issued pursuant to a finance order issued by the NHPUC in January 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)
PSNH Balance Sheets:	As of March 31, 2023		As of December 31, 2022
Restricted Cash - Current Portion (included in Current Assets)	$	18.7	$	32.4
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2
Securitized Stranded Cost (included in Regulatory Assets)	424.9		435.7
Other Regulatory Liabilities (included in Regulatory Liabilities)	8.8		6.0
Accrued Interest (included in Other Current Liabilities)	2.7		6.9
Rate Reduction Bonds - Current Portion	43.2		43.2
Rate Reduction Bonds - Long-Term Portion	388.9		410.5

(Millions of Dollars) PSNH Income Statements:	For the Three Months Ended
	March 31, 2023		March 31, 2022
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	$	10.8	$	10.8
Interest Expense on RRB Principal (included in Interest Expense)	4.1		4.4

8.    PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION

Eversource provides defined benefit retirement plans (Pension Plans) that cover eligible employees.  In addition to the Pension Plans, Eversource maintains non-qualified defined benefit retirement 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) 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.

The components of net periodic benefit plan expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets/(liabilities) for future recovery or refund, are shown below.  The service cost component of net periodic benefit plan 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 plan 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 intercompany allocations of net periodic benefit plan expense/(income), as these amounts are cash settled on a short-term basis.

26

	Pension and SERP								PBOP
	For the Three Months Ended March 31, 2023								For the Three Months Ended March 31, 2023
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Service Cost	$	11.0	$	3.0	$	2.1	$	1.1	$	1.8	$	0.3	$	0.3	$	0.2
Interest Cost	63.7		12.6		13.5		6.8		8.5		1.6		2.3		0.9
Expected Return on Plan Assets	(115.9)		(23.4)		(28.4)		(12.3)		(19.1)		(2.4)		(9.2)		(1.4)
Actuarial Loss	12.5		0.8		4.9		0.4		—		—		—		—
Prior Service Cost/(Credit)	0.3		—		0.1		—		(5.4)		0.3		(4.2)		0.1
Total Net Periodic Benefit Plan Income	$	(28.4)	$	(7.0)	$	(7.8)	$	(4.0)	$	(14.2)	$	(0.2)	$	(10.8)	$	(0.2)
Intercompany Income Allocations	N/A		$	(2.0)	$	(1.7)	$	(0.5)	N/A		$	(0.5)	$	(0.6)	$	(0.2)
	Pension and SERP								PBOP
	For the Three Months Ended March 31, 2022								For the Three Months Ended March 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Service Cost	$	17.7	$	4.5	$	3.6	$	1.8	$	2.8	$	0.5	$	0.5	$	0.2
Interest Cost	38.6		7.8		8.1		4.2		5.0		0.9		1.3		0.5
Expected Return on Plan Assets	(131.7)		(26.6)		(32.0)		(14.1)		(22.4)		(2.8)		(10.6)		(1.6)
Actuarial Loss	30.7		4.2		8.5		2.2		—		—		—		—
Prior Service Cost/(Credit)	0.4		—		0.1		—		(5.4)		0.2		(4.3)		0.1
Total Net Periodic Benefit Plan Income	$	(44.3)	$	(10.1)	$	(11.7)	$	(5.9)	$	(20.0)	$	(1.2)	$	(13.1)	$	(0.8)
Intercompany Income Allocations	N/A		$	(3.8)	$	(2.9)	$	(0.8)	N/A		$	(0.9)	$	(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 March 31, 2023			As of December 31, 2022
	Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)
Eversource	59	$	121.2	59	$	122.6
CL&P	13	13.6		13	13.9
NSTAR Electric	10	3.4		10	3.4
PSNH	8	6.1		8	6.1

Included in the number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured natural 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 $111.7 million and $112.6 million as of March 31, 2023 and December 31, 2022, 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.

27

B.    Guarantees and Indemnifications

In the normal course of business, Eversource parent provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric and PSNH, in the form of guarantees. Management does not anticipate a material impact to net income or cash flows as a result of these various guarantees and indemnifications. 

Guarantees issued on behalf of unconsolidated entities, including equity method offshore wind investments, for which Eversource parent is the guarantor, are recorded at fair value as a liability on the balance sheet at the inception of the guarantee. Eversource regularly reviews performance risk under these guarantee arrangements, 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. The fair value of guarantees issued on behalf of unconsolidated entities are recorded within Other Long-Term Liabilities on the balance sheet, and were $5.4 million and $4.2 million as of March 31, 2023 and December 31, 2022, respectively.

The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries and affiliates to external parties, and primarily relates to its offshore wind business:  

As of March 31, 2023
Company (Obligor)	Description	Maximum Exposure (in millions)		Expiration Dates
North East Offshore LLC	Construction-related purchase agreements with third-party contractors (1)	$	726.2	(1)
Sunrise Wind LLC	Construction-related purchase agreements with third-party contractors (2)	668.6		2025 - 2028
Revolution Wind, LLC	Construction-related purchase agreements with third-party contractors (3)	409.7		2024 - 2027
South Fork Wind, LLC	Construction-related purchase agreements with third-party contractors (4)	126.2		2023 - 2026
Eversource Investment LLC	Funding and indemnification obligations of North East Offshore LLC (5)	68.9		(5)
South Fork Wind, LLC	Power Purchase Agreement Security (6)	7.1		(6)
Sunrise Wind LLC	OREC capacity production (7)	11.0		(7)
Bay State Wind LLC	Real estate purchase	2.5		2023
South Fork Wind, LLC	Transmission interconnection	1.2		—
Eversource Investment LLC	Letters of Credit (8)	4.3		—
Various	Surety bonds (9)	37.2		2023 - 2024
Eversource Service	Lease payments for real estate	0.4		2024

(1)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, North East Offshore LLC (NEO), under which Eversource parent agreed to guarantee 50 percent of NEO’s performance of obligations under certain purchase agreements with third-party contractors, in an aggregate amount not to exceed $1.3 billion with an expiration date in 2025. Eversource parent also issued a separate guarantee to Ørsted on behalf of NEO, under which Eversource parent agreed to guarantee 50 percent of NEO’s payment obligations under certain offshore wind project construction-related agreements with Ørsted in an aggregate amount not to exceed $62.5 million and expiring upon full performance of the guaranteed obligation. Any amounts paid under this guarantee to Ørsted will count toward, but not increase, the maximum amount of the Funding Guarantee described in Note 5, below.

(2)     Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guarantee Sunrise Wind LLC's performance of certain obligations, in an aggregate amount not to exceed $838.4 million, in connection with construction-related purchase agreements. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging from March 2025 and October 2028 and (ii) full performance of the guaranteed obligations.     

(3)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, Revolution Wind, LLC, whereby Eversource parent will guarantee Revolution Wind, LLC's performance of certain obligations, in an aggregate amount not to exceed $547.1 million, in connection with construction-related purchase agreements. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging from May 2024 and November 2027 and (ii) full performance of the guaranteed obligations.

(4)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, South Fork Wind, LLC, whereby Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations in connection with construction-related purchase agreements. Under these guarantees, Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations, in a total aggregate amount not to exceed $207.7 million. Eversource parent’s obligations under these guarantees expire upon the earlier of (i) dates ranging from June 2023 and August 2026 and (ii) full performance of the guaranteed obligations.

(5)    Eversource parent issued a guarantee (Funding Guarantee) on behalf of Eversource Investment LLC (EI), its wholly-owned subsidiary that holds a 50 percent ownership interest in NEO, under which Eversource parent agreed to guarantee certain funding obligations and certain indemnification payments of EI under the operating agreement of NEO, in an amount not to exceed $910 million. The guaranteed obligations include payment of EI's funding obligations during the construction phase of NEO’s underlying offshore wind projects and indemnification obligations associated with third party credit support for its investment in NEO. Eversource parent’s obligations under the Funding Guarantee expire upon the full performance of the guaranteed obligations.

28

(6)    Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, South Fork Wind, LLC, whereby Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations, in an amount not to exceed $7.1 million, under a Power Purchase Agreement between the Long Island Power Authority and South Fork Wind, LLC (the Agreement). The guarantee expires upon the later of (i) the end of the Agreement term and (ii) full performance of the guaranteed obligations.

(7)    Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guarantee 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 by and between the New York State Energy Research and Development Authority (NYSERDA) and Sunrise Wind LLC. The guarantee expires upon the full performance of the guaranteed obligations.

(8)    On September 16, 2020, Eversource parent entered into a guarantee on behalf of EI, which holds Eversource's investments in offshore wind-related equity method investments, under which Eversource parent would guarantee EI's obligations under a letter of credit facility with a financial institution that EI may request in an aggregate amount of up to approximately $25 million. In January 2022, EI issued two letters of credit on behalf of South Fork Wind, LLC related to future decommissioning obligations of certain onshore transmission assets totaling $4.3 million.

(9)    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.

Second Quarter 2023 Guarantees: In the second quarter of 2023, Eversource parent issued an additional guaranty on behalf of Sunrise Wind LLC totaling $86.1 million, whereby Eversource parent will guarantee Sunrise Wind LLC’s performance of certain construction obligations.

C.     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 waste disposal contracts between the Yankee Companies and the DOE. The court previously awarded the Yankee Companies damages for Phases I, II, III and IV of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2016, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.

DOE Phase V Damages - On March 25, 2021, each of the Yankee Companies filed a fifth set of lawsuits against the DOE in the Court of Federal Claims resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2017 to 2020. The Yankee Companies filed claims seeking monetary damages totaling $120.4 million for CYAPC, YAEC and MYAPC. Pursuant to a June 2, 2022 court order, the Yankee Companies were subsequently permitted to include monetary damages relating to the year 2021 in the DOE Phase V complaint. The Yankee Companies submitted a supplemental filing to include these costs of $33.1 million on June 8, 2022. The DOE Phase V trial is now expected to begin in the fourth quarter of 2023.

D.    FERC ROE Complaints

Four separate complaints 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). 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) 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, FERC issued Opinion No. 531-A and 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).

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.

29

Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of both March 31, 2023 and December 31, 2022. 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 both March 31, 2023 and December 31, 2022.

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. 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 illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.

If the results of 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. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC 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. On November 19, 2020, the FERC issued Opinion No. 569-B denying rehearing of Opinion No. 569-A and reaffirmed the methodology previously adopted in Opinion No. 569-A. The new methodology differs significantly from the methodology proposed by FERC in its October 16, 2018 order to determine the NETOs' base ROEs in its four pending cases. FERC Opinion Nos. 569-A and 569-B were appealed to the Court. On August 9, 2022, the Court issued its decision vacating MISO ROE FERC Opinion Nos. 569, 569-A and 569-B and remanded to FERC to reopen the proceedings. The Court found that FERC’s development of the new return methodology was arbitrary and capricious due to FERC’s failure to offer a reasonable explanation for its decision to reintroduce the risk-premium financial model in its new methodology for calculating a just and reasonable return. At this time, Eversource cannot predict how and when FERC will address the Court’s findings on the remand of the MISO FERC opinions or any potential associated impact on the NETOs’ four pending ROE complaint cases.

Given the significant uncertainty regarding the applicability of the FERC opinions in the 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 at this time. As well, Eversource cannot reasonably estimate a range of 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.

A change of 10 basis 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.

30

10.    FAIR VALUE OF FINANCIAL INSTRUMENTS

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

Preferred Stock, 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
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
As of March 31, 2023:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	137.1	$	116.2	$	100.8	$	43.0	$	36.3	$	—	$	—
Long-Term Debt	22,178.0		20,650.5		4,310.2		4,096.9		4,426.0		4,217.4		1,459.4		1,331.7
Rate Reduction Bonds	432.1		417.3		—		—		—		—		432.1		417.3
As of December 31, 2022:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	136.7	$	116.2	$	99.2	$	43.0	$	37.5	$	—	$	—
Long-Term Debt	21,044.1		18,891.3		4,216.5		3,828.3		4,425.1		4,091.8		1,164.6		970.5
Rate Reduction Bonds	453.7		424.7		—		—		—		—		453.7		424.7

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 1C, "Summary of Significant Accounting Policies – Fair Value Measurements," for the fair value measurement policy and the fair value hierarchy.

11.    ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

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

	For the Three Months Ended March 31, 2023								For the Three Months Ended March 31, 2022
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 Gains/(Losses) on Marketable Securities		Defined Benefit Plans		Total
Balance as of Beginning of Period	$	(0.4)	$	(1.2)	$	(37.8)	$	(39.4)	$	(0.4)	$	0.4	$	(42.3)	$	(42.3)
OCI Before Reclassifications	—		—		—		—		—		(0.8)		—		(0.8)
Amounts Reclassified from AOCI	—		1.2		2.0		3.2		—		—		1.5		1.5
Net OCI	—		1.2		2.0		3.2		—		(0.8)		1.5		0.7
Balance as of End of Period	$	(0.4)	$	—	$	(35.8)	$	(36.2)	$	(0.4)	$	(0.4)	$	(40.8)	$	(41.6)

Defined benefit plan OCI amounts reclassified from AOCI relate to the unamortized actuarial gains and losses and prior service costs on the defined benefit plans that are amortized from AOCI into Other Income, Net over the average future employee service period.

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
			Authorized as of March 31, 2023 and December 31, 2022	Issued as of
	Par Value			March 31, 2023	December 31, 2022
Eversource	$	5	380,000,000	359,984,073	359,984,073
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

Treasury Shares: As of March 31, 2023 and December 31, 2022, there were 11,175,991 and 11,540,218 Eversource common shares held as treasury shares, respectively. As of March 31, 2023 and December 31, 2022, there were 348,808,082 and 348,443,855 Eversource common shares outstanding, respectively.

31

Eversource 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. Eversource also issued treasury shares for its October 2022 water business acquisition. 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.

On May 3, 2023, shareholders voted to increase the authorized common shares from 380,000,000 shares to 410,000,000 shares.

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 March 31, 2023 and 2022. 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 March 31, 2023 and December 31, 2022. 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.

14.    EARNINGS PER SHARE

Basic EPS is computed based upon the weighted average number of common shares outstanding during each period.  Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards as if they were converted into outstanding common shares.  The dilutive effect of unvested RSU and performance share awards is calculated using the treasury stock method.  RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. For the three months ended March 31, 2023 and 2022, there were no antidilutive share awards excluded from the computation of diluted EPS.

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

Eversource (Millions of Dollars, except share information)	For the Three Months Ended
	March 31, 2023		March 31, 2022
Net Income Attributable to Common Shareholders	$	491.2	$	443.4
Weighted Average Common Shares Outstanding:
Basic	349,217,147		345,156,346
Dilutive Effect	394,866		504,787
Diluted	349,612,013		345,661,133
Basic and Diluted EPS	$	1.41	$	1.28

15.    REVENUES

The following tables present operating revenues disaggregated by revenue source:

	For the Three Months Ended March 31, 2023
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	$	1,464.0	$	576.6	$	—	$	28.9	$	—	$	—	$	2,069.5
Commercial	788.4		320.0		—		15.5		—		(1.0)		1,122.9
Industrial	89.1		69.6		—		1.1		—		(5.1)		154.7
Total Retail Tariff Sales Revenues	2,341.5		966.2		—		45.5		—		(6.1)		3,347.1
Wholesale Transmission Revenues	—		—		435.0		—		—		(325.3)		109.7
Wholesale Market Sales Revenues	217.3		49.1		—		0.8		—		—		267.2
Other Revenues from Contracts with Customers	18.3		1.5		4.7		2.1		413.8		(412.6)		27.8
Total Revenues from Contracts with Customers	2,577.1		1,016.8		439.7		48.4		413.8		(744.0)		3,751.8
Alternative Revenue Programs	6.0		27.4		18.7		1.7		—		(16.9)		36.9
Other Revenues	5.5		1.0		0.2		0.2		—		—		6.9
Total Operating Revenues	$	2,588.6	$	1,045.2	$	458.6	$	50.3	$	413.8	$	(760.9)	$	3,795.6

32

	For the Three Months Ended March 31, 2022
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	$	1,186.2	$	556.8	$	—	$	28.2	$	—	$	—	$	1,771.2
Commercial	661.3		257.6		—		14.6		—		(1.1)		932.4
Industrial	89.6		68.1		—		1.1		—		(4.5)		154.3
Total Retail Tariff Sales Revenues	1,937.1		882.5		—		43.9		—		(5.6)		2,857.9
Wholesale Transmission Revenues	—		—		446.2		—		24.4		(364.7)		105.9
Wholesale Market Sales Revenues	365.5		33.5		—		0.8		—		—		399.8
Other Revenues from Contracts with Customers	17.7		1.0		3.8		1.9		359.1		(353.1)		30.4
Amortization of/(Reserve for)    Revenues Subject to Refund (1)	58.4		—		—		(0.4)		—		—		58.0
Total Revenues from Contracts with Customers	2,378.7		917.0		450.0		46.2		383.5		(723.4)		3,452.0
Alternative Revenue Programs	4.8		10.2		(15.0)		2.2		—		13.6		15.8
Other Revenues	2.8		0.4		0.2		0.1		—		—		3.5
Total Operating Revenues	$	2,386.3	$	927.6	$	435.2	$	48.5	$	383.5	$	(709.8)	$	3,471.3

	For the Three Months Ended March 31, 2023						For the Three Months Ended March 31, 2022
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	762.2	$	467.8	$	234.0	$	599.1	$	404.6	$	182.5
Commercial	295.3		384.3		108.6		242.2		331.3		88.4
Industrial	33.9		32.6		22.6		33.5		34.1		22.0
Total Retail Tariff Sales Revenues	1,091.4		884.7		365.2		874.8		770.0		292.9
Wholesale Transmission Revenues	195.8		167.8		71.4		209.1		165.2		71.9
Wholesale Market Sales Revenues	154.6		41.1		21.6		279.9		57.9		27.7
Other Revenues from Contracts with Customers	9.3		10.8		2.9		7.9		11.6		2.6
Amortization of Revenues Subject to Refund (1)	0.7		—		—		58.4		—		—
Total Revenues from Contracts with Customers	1,451.8		1,104.4		461.1		1,430.1		1,004.7		395.1
Alternative Revenue Programs	24.6		(9.5)		9.6		1.3		(8.2)		(3.3)
Other Revenues	2.2		2.5		1.0		0.1		2.0		0.9
Eliminations	(139.7)		(141.1)		(51.5)		(145.7)		(135.3)		(53.3)
Total Operating Revenues	$	1,338.9	$	956.3	$	420.2	$	1,285.8	$	863.2	$	339.4

(1)    Amortization of/(Reserve for) Revenues Subject to Refund within the Electric Distribution segment in the first quarter of 2022 represents customer credits being distributed to CL&P’s customers on retail electric bills as a result of the October 2021 CL&P settlement agreement and the 2021 civil penalty for non-compliance with storm performance standards. Total customer credits as a result of the 2021 settlement and civil penalty were $93.4 million. The settlement amount of $65 million was refunded over a two-month billing period from December 1, 2021 to January 31, 2022 and the civil penalty of $28.4 million was refunded over a one year billing period, which began September 1, 2021.    

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 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) the results of other unregulated subsidiaries, which are not part of its core business, and 5) 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., and a renewable energy investment fund that was liquidated in the first quarter of 2023.

33

In the ordinary course of business, Yankee Gas, NSTAR Gas and EGMA purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline project described above. These affiliate transaction costs total $77.7 million annually and are classified as Purchased Power, Purchased Natural Gas and Transmission on the Eversource statements of income.

Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has one 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 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 income/expense.   

Eversource's segment information is as follows:

	For the Three Months Ended March 31, 2023
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Operating Revenues	$	2,588.6	$	1,045.2	$	458.6	$	50.3	$	413.8	$	(760.9)	$	3,795.6
Depreciation and Amortization	(22.0)		(77.0)		(89.9)		(13.3)		(36.8)		2.1		(236.9)
Other Operating Expenses	(2,342.3)		(730.4)		(128.2)		(27.9)		(339.6)		759.3		(2,809.1)
Operating Income	$	224.3	$	237.8	$	240.5	$	9.1	$	37.4	$	0.5	$	749.6
Interest Expense	$	(69.3)	$	(21.2)	$	(41.5)	$	(9.4)	$	(85.1)	$	32.0	$	(194.5)
Other Income, Net	54.3		9.0		9.4		1.1		565.8		(550.6)		89.0
Net Income Attributable to Common Shareholders	165.5		170.3		155.1		1.5		516.9		(518.1)		491.2
Cash Flows Used for Investments in Plant	371.9		165.5		336.6		37.9		65.2		—		977.1

	For the Three Months Ended March 31, 2022
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Operating Revenues	$	2,386.3	$	927.6	$	435.2	$	48.5	$	383.5	$	(709.8)	$	3,471.3
Depreciation and Amortization	(351.6)		(51.9)		(81.9)		(12.3)		(30.2)		1.6		(526.3)
Other Operating Expenses	(1,845.6)		(657.3)		(129.3)		(27.1)		(331.4)		708.8		(2,281.9)
Operating Income	$	189.1	$	218.4	$	224.0	$	9.1	$	21.9	$	0.6	$	663.1
Interest Expense	$	(59.4)	$	(15.8)	$	(33.2)	$	(8.2)	$	(46.8)	$	10.1	$	(153.3)
Other Income, Net	47.6		10.1		8.9		2.2		495.9		(493.1)		71.6
Net Income Attributable to Common Shareholders	140.9		164.0		148.5		3.7		468.7		(482.4)		443.4
Cash Flows Used for Investments in Plant	280.5		127.3		266.9		27.8		62.1		—		764.6

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 March 31, 2023	$	27,978.8	$	8,127.8	$	13,522.6	$	2,804.2	$	27,186.4	$	(25,514.6)	$	54,105.2
As of December 31, 2022	27,365.0		8,084.9		13,369.5		2,783.8		26,365.2		(24,737.5)		53,230.9

34

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, as well as the Eversource 2022 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 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 that is not recognized under GAAP (non-GAAP) and is calculated by dividing the Net Income Attributable to Common Shareholders of each business by the weighted average diluted Eversource common shares outstanding for the period. Our earnings discussion also includes non-GAAP financial measures referencing our earnings and EPS excluding certain transaction and transition costs.

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 results without including these items. This information is among the primary indicators we use as a basis for evaluating performance and planning and forecasting of future periods. We believe the impacts of transaction and transition costs are not indicative of our ongoing costs and performance. We view these charges as not directly related to the ongoing operations of the business and therefore not an indicator of baseline operating performance. Due to the nature and significance of the effect of these items on Net Income Attributable to Common Shareholders and EPS, 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 alternatives to reported Net Income Attributable to Common Shareholders or EPS determined in accordance with GAAP as indicators of operating performance.

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 involve risks and uncertainties that may cause actual results or outcomes to differ materially from those included in our forward-looking statements. 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 may cause our actual results or outcomes 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,

•    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,

•    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,

•    contamination of, or disruption in, our water supplies,

•    changes in levels or timing of capital expenditures,

•    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.

35

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 2022 combined Annual Report on Form 10-K.  This combined Quarterly Report on Form 10-Q and Eversource's 2022 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

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, NSTAR Gas and EGMA (natural gas utilities) and Aquarion (water utilities). Eversource is organized into the electric distribution, electric transmission, natural gas distribution, and water distribution reportable segments.

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 $491.2 million, or $1.41 per share, in the first quarter of 2023, compared with $443.4 million, or $1.28 per share, in the first quarter of 2022. Our results include after-tax transaction and transition costs recorded at Eversource parent of $0.5 million in the first quarter of 2023, compared with $5.3 million, or $0.02 per share, in the first quarter of 2022.

•We reaffirmed our projection to earn within a 2023 non-GAAP earnings guidance range of between $4.25 per share and $4.43 per share, which excludes the potential impact of the strategic review of our offshore wind investment portfolio and transaction costs. We also reaffirmed our projection of our long-term EPS growth rate through 2027 from our regulated utility businesses in the upper half of the 5 to 7 percent range.

Liquidity:

•Cash flows provided by operating activities totaled $69.2 million in the first quarter of 2023, compared with $371.9 million in the first quarter of 2022. Investments in property, plant and equipment totaled $977.1 million in the first quarter of 2023, compared with $764.6 million in the first quarter of 2022.  

•Cash and Cash Equivalents totaled $36.0 million as of March 31, 2023, compared with $374.6 million as of December 31, 2022. Our available borrowing capacity under our commercial paper programs totaled $1.45 billion as of March 31, 2023.

•In the first quarter of 2023, we issued $1.55 billion of new long-term debt and we repaid $400 million of long-term debt.

•On May 3, 2023, our Board of Trustees approved a common share dividend payment of $0.675 per share, payable on June 30, 2023 to shareholders of record as of May 18, 2023. On February 1, 2023, our Board of Trustees approved a common share dividend payment of $0.675 per share, paid on March 31, 2023 to shareholders of record as of March 2, 2023.

36

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 March 31,
	2023				2022
(Millions of Dollars, Except Per Share Amounts)	Amount		Per Share		Amount		Per Share
Net Income Attributable to Common Shareholders (GAAP)	$	491.2	$	1.41	$	443.4	$	1.28
Regulated Companies	$	492.4	$	1.41	$	457.1	$	1.32
Eversource Parent and Other Companies (Non-GAAP)	(0.7)		—		(8.4)		(0.02)
Non-GAAP Earnings	$	491.7	$	1.41	$	448.7	$	1.30
Transaction and Transition Costs (after-tax) (1)	(0.5)		—		(5.3)		(0.02)
Net Income Attributable to Common Shareholders (GAAP)	$	491.2	$	1.41	$	443.4	$	1.28

(1)    The after-tax costs are for the strategic review of our offshore wind investment portfolio and our water business acquisitions. The after-tax costs in 2022 also include costs associated with the transition of systems as a result of our purchase of the assets of Columbia Gas of Massachusetts (CMA) on October 9, 2020 and integrating the CMA assets onto Eversource’s systems.

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 March 31,
	2023				2022
(Millions of Dollars, Except Per Share Amounts)	Amount		Per Share		Amount		Per Share
Electric Distribution	$	165.5	$	0.47	$	140.9	$	0.41
Electric Transmission	155.1		0.45		148.5		0.43
Natural Gas Distribution	170.3		0.49		164.0		0.47
Water Distribution	1.5		—		3.7		0.01
Net Income - Regulated Companies	$	492.4	$	1.41	$	457.1	$	1.32

Our electric distribution segment earnings increased $24.6 million in the first quarter of 2023, as compared to the first quarter of 2022, due primarily to higher revenues at NSTAR Electric as a result of a rate design change approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues and a base distribution rate increase effective January 1, 2023. As part of the 2022 NSTAR Electric rate case decision, certain customer rates changed from seasonal demand charges to a single annual demand charge effective January 1, 2023, resulting in a shift in the timing of revenues and earnings recognized quarterly in 2023, as compared to 2022, but with no impact on an annual basis. This rate design change will result in higher revenues in both the first and fourth quarters of 2023 of approximately $21 million, offset by lower revenues in the third quarter of 2023 of approximately $42 million, as compared to the same periods in 2022. Electric distribution segment earnings were also favorably impacted by higher earnings from CL&P's capital tracking mechanism due to increased electric system improvements and an increase in interest income primarily on regulatory deferrals. Those earnings increases were partially offset by higher operations and maintenance expense, higher interest expense, higher pension expense in Connecticut and New Hampshire, higher property and other tax expense, and higher depreciation expense.

Our electric transmission segment earnings increased $6.6 million in the first quarter of 2023, as compared to the first quarter of 2022, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure, partially offset by higher interest expense on short-term debt.

Our natural gas distribution segment earnings increased $6.3 million in the first quarter of 2023, as compared to the first quarter of 2022, due primarily to base distribution rate increases effective November 1, 2022 at NSTAR Gas and EGMA, higher earnings from capital tracking mechanisms due to continued investments in natural gas infrastructure, and lower operations and maintenance expense. Those earnings increases were partially offset by higher depreciation expense, higher interest expense, and higher property tax expense.

Our water distribution segment earnings decreased $2.2 million in the first quarter of 2023, as compared to the first quarter of 2022, due primarily to higher operations and maintenance expense.

Eversource Parent and Other Companies:  Eversource parent and other companies’ losses decreased $12.5 million in the first quarter of 2023, as compared to the first quarter of 2022, due primarily to a benefit from the liquidation of its equity method investment in a renewable energy fund, partially offset by a charitable contribution made with a portion of the proceeds from the liquidation, and higher interest expense. Additionally, earnings benefited from a decrease in after-tax transaction and transition costs of $4.8 million in the first quarter of 2023, as compared to the same period in 2022 and a lower effective tax rate.

37

Liquidity

Sources and Uses of Cash: Eversource’s regulated business is capital intensive and requires considerable capital resources. Eversource’s regulated companies’ capital resources are provided by cash flows generated from operations, short-term borrowings, long-term debt issuances, capital contributions from Eversource parent, and existing cash, and are used to fund their liquidity and capital requirements. Eversource’s regulated companies typically maintain minimal cash balances and use short-term borrowings to meet their working capital needs and other cash requirements. Short-term borrowings are also used as a bridge to long-term debt financings. The levels of short-term borrowing may vary significantly over the course of the year due to the impact of fluctuations in cash flows from operations (including timing of storm costs and regulatory recoveries), dividends paid, capital contributions received and the timing of long-term debt financings.

Eversource, CL&P, NSTAR Electric and PSNH each uses its available capital resources to fund its respective construction expenditures, meet debt requirements, pay operating costs, including storm-related costs, pay dividends, and fund other corporate obligations, such as pension contributions. Eversource's regulated companies recover their electric, natural gas and water distribution construction expenditures as the related project costs are depreciated over the life of the assets. This impacts the timing of the revenue stream designed to fully recover the total investment plus a return on the equity and debt used to finance the investments. Eversource's regulated companies spend a significant amount of cash on capital improvements and construction projects that have a long-term return on investment and recovery period. In addition, Eversource uses its capital resources to fund investments in its offshore wind business, which are recognized as long-term assets.

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.

Cash and Cash Equivalents totaled $36.0 million as of March 31, 2023, compared with $374.6 million as of December 31, 2022.

Short-Term Debt - Commercial Paper Programs and Credit Agreements: Eversource parent has a $2.00 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas, EGMA and Aquarion Water Company of Connecticut are parties to a five-year $2.00 billion revolving credit facility, which terminates on October 15, 2027. This revolving credit facility serves to backstop Eversource parent's $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 October 15, 2027, and 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
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
(Millions of Dollars)
Eversource Parent Commercial Paper Program	$	1,048.0	$	1,442.2	$	952.0	$	557.8	5.22	%	4.63	%
NSTAR Electric Commercial Paper Program	147.5		—		502.5		650.0		4.77	%	—	%

There were no borrowings outstanding on the revolving credit facilities as of March 31, 2023 or December 31, 2022.

CL&P and PSNH have uncommitted line of credit agreements totaling $450 million and $300 million, respectively, which will expire on May 12, 2023. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of March 31, 2023.

Amounts outstanding under the commercial paper programs are included in Notes Payable and 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.

Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. 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 March 31, 2023, there were intercompany loans from Eversource parent to CL&P of $318.0 million and to PSNH of $121.1 million. As of December 31, 2022, there were intercompany loans from Eversource parent to PSNH of $173.3 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time.

38

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

(Millions of Dollars)	Interest Rate		Issuance/(Repayment)		Issue Date or Repayment Date	Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P 2023 Series A First Mortgage Bonds	5.25	%	$	500.0	January 2023	January 2053	Repaid 2013 Series A Bonds at maturity and short-term debt, and paid capital expenditures and working capital
CL&P 2013 Series A First Mortgage Bonds	2.50	%	(400.0)		January 2023	January 2023	Paid at maturity
PSNH Series W First Mortgage Bonds	5.15	%	300.0		January 2023	January 2053	Repaid short-term debt, paid capital expenditures and working capital
Eversource Parent Series Z Senior Notes	5.45	%	750.0		March 2023	March 2028	Repaid Series F Senior Notes at maturity and short-term debt
Eversource Parent Series F Senior Notes	2.80	%	(450.0)		May 2023	May 2023	Paid at maturity

Rate Reduction Bonds: PSNH's RRB payments consist of principal and interest and are paid semi-annually. PSNH paid $21.6 million of RRB principal payments and $8.3 million of interest payments in the first quarter of 2023, and paid $21.6 million of RRB principal payments and $9.0 million of interest payments in the first quarter of 2022.

Cash Flows:  Cash flows from operating activities primarily result from the transmission and distribution of electricity, and the distribution of natural gas and water. Cash flows provided by operating activities totaled $69.2 million in the first quarter of 2023, compared with $371.9 million in the first quarter of 2022. Operating cash flows were unfavorably impacted by an increase in regulatory under-recoveries driven primarily by the timing of collections for the CL&P non-bypassable FMCC and other regulatory tracking mechanisms, including energy supply, and the timing of cash payments made on our accounts payable. In 2023, CL&P increased the flow back to customers of net revenues generated by long-term state-approved energy contracts by providing these credits to customers through the non-bypassable FMCC retail rate. The reduction in the CL&P non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $286.6 million in the first quarter of 2023, as compared to the first quarter of 2022, and is presented as a cash outflow in Amortization on the statement of cash flows.  The impact of regulatory collections are included in both Regulatory Recoveries and Amortization on the statements of cash flows. These unfavorable impacts were partially offset by a $71.2 million decrease in cash payments for storm costs, the timing of cash collections on our accounts receivable, the absence in 2023 of $58.4 million of customer credits distributed in 2022 at CL&P as a result of the October 2021 settlement agreement and the 2021 storm performance penalty for CL&P’s response to Tropical Storm Isaias, a decrease of $25.0 million in pension contributions made in 2023, as compared to 2022, the timing of other working capital items, and an $8.4 million decrease in income tax payments made in 2023, as compared to 2022.

Effective July 1, 2023, CL&P’s non-bypassable FMCC retail rate will change to $0.00000 per kWh, as compared to a credit of $0.01524 per kWh from January 1, 2023 to June 30, 2023. The increase in the retail rate will result in higher cash collections in the second half of 2023, as compared to the first half of 2023.

On May 3, 2023, our Board of Trustees approved a common share dividend payment of $0.675 per share, payable on June 30, 2023 to shareholders of record as of May 18, 2023. On February 1, 2023, our Board of Trustees approved a common share dividend payment of $0.675 per share, paid on March 31, 2023 to shareholders of record as of March 2, 2023. In the first quarter of 2023, we paid cash dividends of $229.4 million and issued non-cash dividends of $6.0 million in the form of treasury shares, totaling dividends of $235.4 million. In the first quarter of 2022, we paid cash dividends of $213.9 million and issued non-cash dividends of $5.9 million in the form of treasury shares, totaling dividends of $219.8 million.

Eversource 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 quarter of 2023, CL&P, NSTAR Electric and PSNH paid $82.6 million, $327.4 million, and $28.0 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 income/expense.  In the first quarter of 2023, investments for Eversource, CL&P, NSTAR Electric, and PSNH were $977.1 million, $255.9 million, $318.7 million, and $133.9 million, respectively. Capital expenditures were primarily for continuing projects to maintain and improve infrastructure and operations, including enhancing reliability to the transmission and distribution systems.

Investments in Unconsolidated Affiliates within investing activities on the statements of cash flows includes proceeds received from the liquidation of an equity method investment in a renewable energy investment fund of $123.4 million in the first quarter of 2023.

Contractual Obligations: Our cash requirements from contractual obligations were reported in Item 7, "Management’s Discussion and Analysis of Financial Condition and Results of Operations," of the Eversource 2022 Form 10-K. There have been no material changes to our cash requirements from contractual obligations and payment schedules previously disclosed in our 2022 Form 10-K.

39

Impact of COVID-19

The financial impacts of COVID-19 as it relates to our businesses primarily relate to collectability of customer receivables and the outcome of future proceedings before our state regulatory commissions to recover our incremental uncollectible customer receivable costs associated with COVID-19. As of both March 31, 2023 and December 31, 2022, the total amount incurred as a result of COVID-19 included in the allowance for uncollectible accounts was $50.9 million at Eversource, $16.0 million at CL&P, and $4.1 million at NSTAR Electric. At our Connecticut and Massachusetts utilities, the 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 future rates.

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 income/expense (all of which are non-cash factors), totaled $789.2 million in the first quarter of 2023, compared to $685.6 million in the first quarter of 2022.  These amounts included $42.9 million and $53.7 million in the first quarter of 2023 and 2022, 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 increased by $16.3 million in the first quarter of 2023, as compared to the first quarter of 2022.  A summary of electric transmission capital expenditures by company is as follows:  

	For the Three Months Ended March 31,
(Millions of Dollars)	2023		2022
CL&P	$	77.4	$	93.8
NSTAR Electric	96.6		83.4
PSNH	72.8		53.3
Total Electric Transmission	$	246.8	$	230.5

Our transmission projects are designed to improve the reliability of the electric grid, meet customer demand for power and increases in electrification of municipal infrastructure, strengthen the electric grid's resilience against extreme weather and other safety and security threats, and enable integration of increasing amounts of clean power generation from renewable sources, such as solar, battery storage, and offshore wind. In Connecticut, Massachusetts and New Hampshire, our transmission projects include transmission line upgrades, the installation of new transmission interconnection facilities, substations and lines, and transmission substation enhancements.

Our transmission projects in Massachusetts include electric transmission upgrades in the greater Boston metropolitan area. Two of these upgrades, the Mystic-Woburn and the Wakefield-Woburn reliability projects, are under construction and are expected to be placed in service by the fourth quarter of 2023. Construction on the last remaining upgrade, the Sudbury-Hudson Reliability Project, commenced in the fourth quarter of 2022. We spent $16.6 million during the first quarter of 2023 and we now expect to make additional capital expenditures of approximately $235 million on these remaining transmission upgrades. There are also several transmission projects underway 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. We spent $7.2 million during the first quarter of 2023 and we expect to make additional capital expenditures of approximately $100 million on these transmission upgrades.

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

	For the Three Months Ended March 31,
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		Total Electric		Natural Gas		Water		Total
2023
Basic Business	$	53.1	$	62.0	$	11.7	$	126.8	$	37.1	$	3.5	$	167.4
Aging Infrastructure	52.1		59.4		16.5		128.0		105.5		27.7		261.2
Load Growth and Other	25.7		31.3		3.1		60.1		10.6		0.2		70.9
Total Distribution	$	130.9	$	152.7	$	31.3	$	314.9	$	153.2	$	31.4	$	499.5
2022
Basic Business	$	59.3	$	27.3	$	13.5	$	100.1	$	54.9	$	1.8	$	156.8
Aging Infrastructure	34.2		48.6		12.4		95.2		61.2		23.6		180.0
Load Growth and Other	14.0		36.5		5.2		55.7		8.8		0.1		64.6
Total Distribution	$	107.5	$	112.4	$	31.1	$	251.0	$	124.9	$	25.5	$	401.4

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.

40

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 of acquisitions, installation of new services, and interconnections of systems.

Offshore Wind Business: Our offshore wind business includes a 50 percent ownership interest in North East Offshore, which holds PPAs and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind projects, as well as an undeveloped offshore lease area. Our offshore wind projects are being developed and constructed through a joint and equal partnership with Ørsted.

The offshore leases include a 257 square-mile ocean lease off the coasts of Massachusetts and Rhode Island and a separate, adjacent 300-square-mile ocean lease located approximately 25 miles south of the coast of Massachusetts. In aggregate, these ocean lease sites jointly-owned by Eversource and Ørsted could eventually develop at least 4,000 MW of clean, renewable offshore wind energy.

As of March 31, 2023 and December 31, 2022, Eversource's total equity investment balance in its offshore wind business was $2.16 billion and $1.95 billion, respectively. This equity investment includes capital expenditures for the three projects, as well as capitalized costs related to future development, acquisition costs of offshore lease areas, and capitalized interest.

Strategic Review of Offshore Wind Investments: On May 4, 2022, we announced that we had initiated a strategic review of our offshore wind investment portfolio. As part of that review, we are exploring strategic alternatives that could result in a potential sale of all, or part, of our 50 percent interest in our offshore wind partnership with Ørsted. We continue to work with interested parties through this ongoing process and expect to complete this review in the second quarter of 2023. If the recommended path forward following the strategic review is a sale of all, or part, of our interest in the partnership, we expect potential proceeds from such transaction would likely be used to support our regulated investments in strengthening, modernizing and decarbonizing our regulated energy and water delivery systems. We currently believe that the fair market value of our offshore wind investment is greater than the carrying value; however, there could be changes in market conditions that would impact our ability to sell this investment or realize a value in excess of our carrying value. As the strategic review proceeds, we remain committed to continue providing oversight of the siting and construction of onshore elements of our South Fork Wind, Revolution Wind and Sunrise Wind offshore wind projects.

Contracts, Permitting and Construction of Offshore Wind Projects: 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	Pricing Terms	Contract Status
Revolution Wind	Rhode Island	400	20	$98.43	Fixed price contract; no price escalation	Approved
Revolution Wind	Connecticut	304	20	$98.43 - $99.50	Fixed price contracts; no price escalation	Approved
South Fork Wind	New York (LIPA)	90	20	$160.33	2 percent average price escalation	Approved
South Fork Wind	New York (LIPA)	40	20	$86.25	2 percent average price escalation	Approved
Sunrise Wind	New York (NYSERDA)	924	25	$110.37 (1)	Fixed price contract; no price escalation	Approved

(1)    Index Offshore Wind Renewable Energy Certificate (OREC) strike price.

Revolution Wind and Sunrise Wind projects are subject to receipt of federal, state and local approvals necessary to construct and operate the projects. The federal permitting process is led by BOEM, and state approvals are required from New York, Rhode Island 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 could adversely impact the timing of these projects' in-service dates.

Federal Siting and Permitting Process: The federal siting and permitting process for each of our offshore wind projects commence with the filing of a Construction and Operations Plan (COP) application with BOEM. The first major milestone in the BOEM review process is an issuance of a Notice of Intent (NOI) to complete an Environmental Impact Statement (EIS). BOEM then provides a final review schedule for the project’s COP approval. BOEM conducts environmental and technical reviews of the COP. The EIS assesses the environmental, social, and economic impacts of constructing the project and recommends measures to minimize impacts. The Final EIS will inform BOEM in deciding whether to approve the project or to approve with modifications and BOEM will then issue its Record of Decision. BOEM issues its final approval of the COP following the Record of Decision.

Revolution Wind and Sunrise Wind filed their COP applications with BOEM in March 2020 and September 2020, respectively. BOEM released its Draft EIS on September 2, 2022 for the Revolution Wind project and on December 16, 2022 for the Sunrise Wind project. The Draft EIS analyzes the potential environmental impacts of the project and the alternatives to the project to be evaluated as part of the process. Each of the identified alternative configurations in the Draft EISs had a similar level of environmental impacts, and if an alternative configuration was selected, the Revolution Wind project and the Sunrise Wind project would each still meet their respective contractual output requirements. For Revolution Wind, a final EIS is expected in the second quarter of 2023, the Record of Decision in the third quarter of 2023, and final approval is

41

expected in the fourth quarter of 2023. For Sunrise Wind, a final EIS and Record of Decision are expected in the third quarter of 2023, and final approval is expected in the fourth quarter of 2023.

South Fork Wind, Revolution Wind and Sunrise Wind are each designated as a “Covered Project” pursuant to Title 41 of the Fixing America’s Surface Transportation Act (FAST41) and a Major Infrastructure Project under Section 3(e) of Executive Order 13807, which provides greater federal attention on meeting the projects’ permitting timelines.

State and Local Siting and Permitting Process: State permitting applications in Rhode Island for Revolution Wind and in New York for Sunrise Wind were filed in December 2020. On July 8, 2022, the Rhode Island Energy Facilities Siting Board issued a Final Decision and Order approving the Revolution Wind project and granting a license to construct and operate.

On September 23, 2022, Sunrise Wind filed a Joint Proposal to the New York State Public Service Commission. Among other things, the Joint Proposal includes proposed mitigation for certain environmental, community and construction impacts associated with constructing the project. The Joint Proposal was signed by the New York Departments of Public Service, Environmental Conservation, Transportation and State as well as the Office of Agriculture and Markets and the Long Island Commercial Fisheries Association. On November 17, 2022, the New York Public Service Commission approved an order adopting the Joint Proposal and granting a Certificate of Environmental Compatibility and Public Need. On November 18, 2022, Sunrise Wind filed its Phase 1 Environmental Management and Construction Plan (EM&CP) with the New York Public Service Commission, which details the plans on how the advanced components of the project will be constructed in accordance with the conditions of the approved Joint Proposal. On March 27, 2023, Sunrise Wind filed its EM&CP for Phase 2, which covers the remainder of the project components. Comments from the reviewing agencies and parties have been addressed and approval of the Phase 1 EM&CP is expected in the second quarter of 2023.

On November 9, 2022, the Towns of Brookhaven and Suffolk County executed the easements and other real estate rights necessary to construct the Sunrise Wind project. On November 28, 2022, the Town of North Kingstown and the Quonset Development Corporation approved Revolution Wind’s real estate PILOT terms and the personal property PILOT agreement necessary to construct the Revolution Wind project.

Construction Process: South Fork Wind received all required approvals to start construction and the project entered the construction phase in early 2022. Onshore activities for the project’s underground onshore transmission line were completed in the first quarter of 2023. Onshore activities for the construction of the onshore interconnection facility located in East Hampton, New York continue. Offshore construction activities began in the fourth quarter of 2022 and continue, with the sea-to-shore conduit system and half of the subsea transmission cable completed in the first quarter of 2023. The remainder of the marine construction activities, including the project’s monopile foundations, 11-megawatt wind turbines, and offshore substation, are expected to continue throughout the rest of 2023. Construction-related purchase agreements with third-party contractors and materials contracts have largely been secured. South Fork Wind faces several challenges and appeals of New York State and federal agency approvals, however it believes it is probable it will be able to overcome these challenges.

For Revolution Wind and Sunrise Wind, construction is expected to begin in the second half of 2023 once all necessary federal, state and local approvals are received.

Projected In-Service Dates: We expect the South Fork Wind project to be in-service by the end of 2023. For Revolution Wind and Sunrise Wind, based on the BOEM permit schedule included in each respective NOI outlining when BOEM will complete its review of the COP, we currently expect in-service dates in 2025 for both projects.

Projected Investments: For Revolution Wind and Sunrise Wind, 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. Construction of South Fork Wind is underway. Construction-related purchase agreements with third-party contractors and materials contracts have largely been secured. Subject to advancing our final project designs and federal, state and local permitting processes and construction schedules, we currently expect to make investments in our offshore wind business between $1.4 billion and $1.6 billion in 2023 and expect to make investments for our three projects in total between $2.1 billion and $2.4 billion from 2024 through 2026. These estimates assume that the three projects are completed and are in-service by the end of 2025, as planned. These projected investments could be impacted by the strategic review of our offshore wind investment.

FERC Regulatory Matters

FERC ROE Complaints: Four separate complaints 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). 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) 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, FERC issued Opinion No. 531-A and 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).

42

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 both March 31, 2023 and December 31, 2022. 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 both March 31, 2023 and December 31, 2022.

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. 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 illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.

If the results of 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. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC 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. On November 19, 2020, the FERC issued Opinion No. 569-B denying rehearing of Opinion No. 569-A and reaffirmed the methodology previously adopted in Opinion No. 569-A. The new methodology differs significantly from the methodology proposed by FERC in its October 16, 2018 order to determine the NETOs' base ROEs in its four pending cases. FERC Opinion Nos. 569-A and 569-B were appealed to the Court. On August 9, 2022, the Court issued its decision vacating MISO ROE FERC Opinion Nos. 569, 569-A and 569-B and remanded to FERC to reopen the proceedings. The Court found that FERC’s development of the new return methodology was arbitrary and capricious due to FERC’s failure to offer a reasonable explanation for its decision to reintroduce the risk-premium financial model in its new methodology for calculating a just and reasonable return. At this time, Eversource cannot predict how and when FERC will address the Court’s findings on the remand of the MISO FERC opinions or any potential associated impact on the NETOs’ four pending ROE complaint cases.

Given the significant uncertainty regarding the applicability of the FERC opinions in the 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 at this time. As well, Eversource cannot reasonably estimate a range of 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.

A change of 10 basis 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. Prospectively from the date of a final FERC order implementing a new base ROE, based off of estimated 2022 rate base, a change of 10 basis points to the base ROE would impact Eversource’s future annual after-tax earnings by approximately $5 million per year, and will increase slightly over time as we continue to invest in our transmission infrastructure.

FERC Notice of Inquiry on ROE: On March 21, 2019, FERC issued a Notice of Inquiry (NOI) seeking comments from all stakeholders on FERC's policies for evaluating ROEs for electric public utilities, and interstate natural gas and oil pipelines. On June 26, 2019, the NETOs jointly filed comments supporting the methodology established in the FERC’s October 16, 2018 order with minor enhancements going forward. 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 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. Eversource filed reply comments 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.

43

On April 15, 2021, FERC issued a Supplemental NOPR that proposes to eliminate the existing 50 basis point return on equity for utilities that have been participating in a regional transmission organization (RTO ROE incentive) for more than three years. On June 25, 2021, the NETOs jointly filed comments strongly opposing FERC’s proposal. On July 26, 2021, the NETOs filed Supplemental NOPR reply comments responding to various parties advocating for the elimination of the RTO Adder. If FERC issues a final order eliminating the RTO ROE incentive as proposed in the Supplemental NOPR, the estimated annual impact (using 2022 estimated rate base) on Eversource's after-tax earnings is approximately $18 million. The Supplemental NOPR contemplates an effective date 30 days from the final order.

At this time, Eversource cannot predict the ultimate outcome of these proceedings, including possible appellate review, and the resulting impact on its transmission incentives.

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 quarter of 2023, changes made to the regulated companies’ rates did not have a material impact on their earnings.  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 2022 Form 10-K.

Energy Supply Retail Rates: CL&P, NSTAR Electric and PSNH are in the process of finalizing, or have finalized, full requirements energy supply procurement contracts for its customers that choose to purchase power from the electric distribution company (standard offer, basic service or default energy service, respectively) for the second half of 2023 and each anticipates that energy supply retail rates will decrease in the second half of 2023, as compared to the first half of 2023. Energy supply rates are approved by the respective state regulatory commission and are re-set every six months for residential customers. New energy supply rates for residential customers will be established effective July 1, 2023 at CL&P and NSTAR Electric and effective August 1, 2023 at PSNH. Decreases in energy supply retail rates will result in decreases in both energy supply procurement revenues and purchased power expenses, with no impact on earnings.

Connecticut:

CL&P Performance Based Rate Making: On May 26, 2021, in accordance with an October 2020 Connecticut law, PURA opened a proceeding to begin to evaluate and eventually implement performance-based regulation (PBR) for electric distribution companies. PURA will conduct the proceeding in two phases. On January 25, 2023, PURA staff issued a proposal outlining a suggested portfolio of performance-based regulation elements for further exploration and implementation in the second phase of the proceeding. On April 26, 2023, PURA issued a final decision on the first phase and identified various objectives to guide PBR development and evaluate adoption of a PBR framework. The decision included a tentative procedural schedule for Phase 2 with final decisions expected in May and August of 2024. At this time, we cannot predict the ultimate outcome of this proceeding and the resulting impact to CL&P.

Aquarion Water Company of Connecticut Distribution Rate Case: On August 29, 2022, Aquarion Water Company of Connecticut (AWC-CT) filed an application with PURA to amend its existing rate schedules to address an operating revenue deficiency. AWC-CT’s rate application requested approval of rate increases of $27.5 million, an additional $13.6 million, and an additional $8.8 million, effective March 15, 2023, 2024, and 2025, respectively. On March 15, 2023, PURA issued a final decision that rejected this request. In this decision, PURA ordered a base distribution rate decrease of $2.0 million effective March 15, 2023. The decision allows an authorized regulatory ROE of 8.70 percent. On March 30, 2023, AWC-CT filed an appeal on the decision and a request for stay of enforcement of agency decision with the State of Connecticut Superior Court. On April 5, 2023, the Court temporarily granted AWC-CT’s request to stay until further order and pending a hearing, which is scheduled in the second quarter of 2023.

New Hampshire:

PSNH Pole Acquisition Approval: On November 18, 2022, the NHPUC issued a decision that approved a proposed purchase agreement between PSNH and Consolidated Communications, in which PSNH would acquire approximately 343,000 jointly-owned utility poles and approximately 3,800 solely-owned poles and pole assets. The NHPUC also authorized PSNH to recover certain expenses associated with the operation and maintenance of the transferred poles, pole inspections, and vegetation management expenses through a new cost recovery mechanism, the Pole Plant Adjustment Mechanism (PPAM), subject to consummation of the purchase agreement. The purchase agreement was finalized on May 1, 2023 for a purchase price of approximately $23 million.

Critical Accounting Policies

The preparation of financial statements in conformity with GAAP requires management to make estimates, assumptions and, at times, difficult, subjective or complex judgments.  Changes in these estimates, assumptions and judgments, in and of themselves, could materially impact our financial position, results of operations or cash flows.  Our management discusses with the Audit Committee of our Board of Trustees significant matters relating to critical accounting policies.  Our critical accounting policies that we believed were the most critical in nature were reported in the Eversource 2022 Form 10-K.  There have been no material changes with regard to these critical accounting policies.

44

Other Matters

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 months ended March 31, 2023 and 2022 included in this combined Quarterly Report on Form 10-Q:  

	For the Three Months Ended March 31,
(Millions of Dollars)	2023		2022		Increase/(Decrease)
Operating Revenues	$	3,795.6	$	3,471.3	$	324.3
Operating Expenses:
Purchased Power, Purchased Natural Gas and Transmission	1,903.2		1,389.7		513.5
Operations and Maintenance	454.6		472.4		(17.8)
Depreciation	313.0		289.3		23.7
Amortization	(76.1)		236.9		(313.0)
Energy Efficiency Programs	222.9		199.5		23.4
Taxes Other Than Income Taxes	228.4		220.4		8.0
Total Operating Expenses	3,046.0		2,808.2		237.8
Operating Income	749.6		663.1		86.5
Interest Expense	194.5		153.3		41.2
Other Income, Net	89.0		71.6		17.4
Income Before Income Tax Expense	644.1		581.4		62.7
Income Tax Expense	151.0		136.1		14.9
Net Income	493.1		445.3		47.8
Net Income Attributable to Noncontrolling Interests	1.9		1.9		—
Net Income Attributable to Common Shareholders	$	491.2	$	443.4	$	47.8

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
	Sales Volumes (GWh)		Percentage Decrease		Sales Volumes (MMcf)		Percentage Decrease		Sales Volumes (MG)		Percentage (Decrease)/Increase
Three Months Ended March 31:	2023	2022			2023	2022			2023	2022
Traditional	1,900	1,992	(4.6)	%	—	—	—	%	313	324	(3.4)	%
Decoupled and Special Contracts (1)	10,298	10,973	(6.2)	%	59,783	68,518	(12.7)	%	4,592	4,342	5.8	%
Total Sales Volumes	12,198	12,965	(5.9)	%	59,783	68,518	(12.7)	%	4,905	4,666	5.1	%

(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.

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 above).  For CL&P, NSTAR Electric, NSTAR Gas, EGMA, Yankee 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.

45

Operating Revenues: Operating Revenues by segment increased for the three months ended March 31, 2023, as compared to the same period in 2022, as follows:

(Millions of Dollars)	Three Months Ended
Electric Distribution	$	202.3
Natural Gas Distribution	117.6
Electric Transmission	23.4
Water Distribution	1.8
Other	30.3
Eliminations	(51.1)
Total Operating Revenues	$	324.3

Electric and Natural Gas Distribution Revenues:

Base Distribution Revenues:

•Base electric distribution revenues increased $28.9 million for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the result of a rate design change at NSTAR Electric approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues (increase of $20.7 million in 2023, as compared to 2022) and a base distribution rate increase effective January 1, 2023 at NSTAR Electric (increase of $9.9 million in 2023, as compared to 2022). As part of the 2022 NSTAR Electric rate case decision, certain customer rates changed from seasonal demand charges to a single annual demand charge effective January 1, 2023, resulting in a shift in the timing of revenues and earnings recognized quarterly in 2023, as compared to 2022, but with no impact on an annual basis. This rate design change will result in higher revenues in both the first and fourth quarters of 2023 of approximately $21 million, offset by lower revenues in the third quarter of 2023 of approximately $42 million, as compared to the same periods in 2022.

•Base natural gas distribution revenues increased $10.9 million for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the impact of base distribution rate increases at NSTAR Gas and EGMA effective November 1, 2022.

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 has no impact on earnings.  Revenues from certain of these cost tracking mechanisms also include certain incentives earned, return 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, electric retail transmission charges, energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), certain capital tracking mechanisms for infrastructure improvements, and additionally for the Massachusetts utilities, pension and PBOP benefits, net metering for distributed generation, and solar-related programs. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market, sales of natural gas to third party marketers, and the sale of RECs to various counterparties.

Customers have the choice to purchase electricity from each Eversource electric utility or from a competitive third party supplier. For customers who have contracted separately with these competitive suppliers, revenue is not recorded for the sale of the electricity commodity, as the utility is acting as an agent on behalf of the third party supplier. For customers that choose to purchase electric generation from CL&P, NSTAR Electric or PSNH, each purchases power on behalf of, and is permitted to recover the related energy supply cost without mark-up from, its customers, and records offsetting amounts in revenues and purchased power and amortization expense related to this energy supply procurement. CL&P, NSTAR Electric and PSNH each remain as the distribution service provider for all customers and charge a regulated rate for distribution delivery service recorded in revenues. Certain eligible natural gas customers may elect to purchase natural gas from each Eversource natural gas utility or may contract separately with a gas supply operator. Revenue is not recorded for the sale of the natural gas commodity to customers who have contracted separately with these operators, only the delivery to a customer, as the utility is acting as an agent on behalf of the gas supply operator.

Tracked distribution revenues increased/(decreased) for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

	Electric Distribution		Natural Gas Distribution
(Millions of Dollars)	Three Months Ended		Three Months Ended
Retail Tariff Tracked Revenues:
Energy supply procurement	$	475.1	$	63.9
CL&P FMCC	(139.3)		—
Retail transmission	(19.3)		—
Energy efficiency	10.0		18.4
Other distribution tracking mechanisms	(3.7)		10.3
Wholesale Market Sales Revenue	(148.2)		15.6

The increase in energy supply procurement within electric distribution and natural gas distribution for the three months ended March 31, 2023, as compared to the same period in 2022, was driven by higher average prices, partially offset by lower average supply-related sales volumes. Fluctuations in retail transmission revenues are driven by the recovery of the costs of our wholesale transmission business, such as those billed by ISO-NE and Local and Regional Network Service charges. For further information, see "Purchased Power, Purchased Natural Gas and Transmission Expense" below.

46

The decrease in CL&P’s FMCC revenues was driven by a decrease in the retail Non-Bypassable Federally Mandated Congestion Charge (NBFMCC) rate, which reflects the impact of returning net benefits of higher wholesale market sales received in the ISO-NE market for long-term state approved energy contracts at CL&P, which are then credited back to customers through the retail NBFMCC rate. The average NBFMCC rate in the first quarter of 2023 was a credit to customers of $0.01300 per kWh, as compared to a charge to customers of $0.01460 per kWh in the first quarter of 2022. As a result of the CL&P RAM proceeding in Docket No. 22-01-03, CL&P reduced the NBFMCC rate effective September 1, 2022 from $0.01251 per kWh to $0.00000 per kWh. As part of a November 2022 rate relief plan, CL&P further reduced the NBFMCC rate effective January 1, 2023 to a credit of $0.01524 per kWh. These rate reductions returned to customers the net revenues generated by long-term state-approved energy contracts with the Millstone and Seabrook nuclear power plants. The NBFMCC rate will change to $0.00000 per kWh effective July 1, 2023.

The decrease in electric distribution wholesale market sales revenue for the three months ended March 31, 2023, as compared to the same period in 2022, was due primarily to lower average electricity market prices received for wholesale sales at CL&P, NSTAR Electric and PSNH. ISO-NE average market prices received for CL&P’s wholesale sales decreased to an average price of $48.95 per MWh for the three months ended March 31, 2023, as compared to $105.35 per MWh for the three months ended March 31, 2022, driven primarily by lower natural gas prices in New England. Volumes sold into the market were primarily from the sale of output generated by the Millstone PPA and Seabrook PPA that CL&P entered into in 2019, as required by regulation. CL&P sells the energy purchased from Millstone and Seabrook into the wholesale market and uses the proceeds from the energy sales to offset the contract costs. The net sales or net cost amount is refunded to, or recovered from, customers in the non-bypassable component of the CL&P FMCC rate.

Electric Transmission Revenues:  Electric transmission revenues increased $23.4 million for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure.

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 in rates charged to their customers.

Purchased Power, Purchased Natural Gas and Transmission expense includes costs associated with purchasing electricity and natural gas on behalf of our customers and the cost of energy purchase contracts, as required by regulation.  These electric and natural gas supply costs and other energy-related costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs).  Purchased Power, Purchased Natural Gas and Transmission expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

(Millions of Dollars)	Three Months Ended
Purchased Power Costs	$	479.9
Natural Gas Costs	56.1
Transmission Costs	(6.8)
Eliminations	(15.7)
Total Purchased Power, Purchased Natural Gas and Transmission	$	513.5

The increase in purchased power expense at the electric distribution business for the three months ended March 31, 2023, as compared to the same period in 2022, was driven primarily by higher energy supply procurement costs resulting from higher average prices, partially offset by lower average supply-related sales volumes. The increase was also due to higher long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism at CL&P and higher net metering costs at CL&P, partially offset by a decrease in the cost deferral associated with long-term renewable contracts at NSTAR Electric and lower net metering costs at NSTAR Electric.

The increase in costs at the natural gas distribution segment for the three months ended March 31, 2023, as compared to the same period in 2022, was due primarily to higher average prices, partially offset by lower average supply-related sales volumes.

The decrease in transmission costs for the three months ended March 31, 2023, as compared to the same period in 2022, was primarily the result of a decrease in costs billed by ISO-NE that support regional grid investments. This decrease was partially offset by an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network, and an increase in the retail transmission cost deferral, which reflects the actual cost of transmission service compared to estimated amounts billed to customers.

47

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 decreased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

(Millions of Dollars)	Three Months Ended
Base Electric Distribution (Non-Tracked Costs):
Shared corporate costs (including computer software depreciation at Eversource Service)	$	9.5
General costs (including vendor services in corporate areas, insurance, fees and assessments)	7.1
Operations-related expenses (including storm costs, vendor services and vehicles)	5.5
Employee-related expenses, including labor and benefits	2.6
Vegetation management	(5.3)
Other non-tracked operations and maintenance	(7.9)
Total Base Electric Distribution (Non-Tracked Costs)	11.5
Tracked Electric Costs (Electric Distribution and Electric Transmission)	1.1
Total Electric Distribution and Electric Transmission	12.6
Natural Gas Distribution:
Base (Non-Tracked Costs)	(3.7)
Tracked Costs	(1.6)
Total Natural Gas Distribution	(5.3)
Water Distribution	0.7
Parent and Other Companies and Eliminations:
Eversource Parent and Other Companies - other operations and maintenance	14.8
Transaction and Transition Costs	(6.5)
Eliminations	(34.1)
Total Operations and Maintenance	$	(17.8)

Depreciation expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to higher utility plant in service balances, partially offset by a decrease in approved depreciation rates as part of the rate case decision effective January 1, 2023 at NSTAR Electric.

Amortization expense includes the deferral of energy-related costs and other costs that are included in certain regulatory commission-approved cost tracking mechanisms. This deferral adjusts expense to match the corresponding revenues compared to the actual costs incurred. These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of certain costs as those costs are collected in rates.

Amortization decreased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the deferral adjustment of energy-related and other tracked costs at CL&P (included in the non-bypassable component of the FMCC mechanism), NSTAR Electric and PSNH, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The decrease in the CL&P FMCC mechanism was driven primarily by the November 2022 rate relief plan, which reduced the non-bypassable FMCC rate effective January 1, 2023. The reduction in the CL&P non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $286.6 million in the first quarter of 2023, as compared to the first quarter of 2022. The decrease was partially offset by the amortization of historical exogenous property taxes that were approved for recovery effective January 1, 2023 in the November 2022 NSTAR Electric distribution rate case decision and effective November 1, 2022 at NSTAR Gas and EGMA.

Energy Efficiency Programs expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the deferral adjustment at NSTAR Electric and 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 costs for the majority of the state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates and have no impact on earnings.

Taxes Other Than Income Taxes expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to higher Connecticut gross earnings taxes, partially offset by a decrease in property taxes due to lower mill rates at NSTAR Electric and PSNH.

Interest Expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to an increase in interest on long-term debt as a result of new debt issuances ($44.6 million), an increase in interest on short-term notes payable ($14.1 million), an increase in interest expense on regulatory deferrals ($2.6 million), and higher amortization of debt discounts and premiums, net ($1.3 million), partially offset by an increase in capitalized AFUDC related to debt funds and other capitalized interest ($13.8 million), lower interest resulting from the payment of withheld property taxes in the second quarter of 2022 at NSTAR Electric ($1.6 million) and a decrease in RRB interest expense ($0.3 million).

48

Other Income, Net increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to an increase in interest income primarily from regulatory deferrals ($16.4 million), an increase in capitalized AFUDC related to equity funds ($5.6 million), and an increase in equity in earnings related to Eversource's equity method investments ($3.4 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($19.5 million) and higher investment losses driven by market volatility ($1.5 million).

Income Tax Expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to higher pre-tax earnings ($13.2 million), lower share-based payment excess tax benefits ($2.6 million), a decrease in amortization of EDIT ($1.5 million), and an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($1.6 million), partially offset by lower state taxes ($4.0 million).

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 three months ended March 31, 2023 and 2022 included in this combined Quarterly Report on Form 10-Q:

	For the Three Months Ended March 31,
	CL&P						NSTAR Electric						PSNH
(Millions of Dollars)	2023		2022		Increase/ (Decrease)		2023		2022		Increase/ (Decrease)		2023		2022		Increase/ (Decrease)
Operating Revenues	$	1,338.9	$	1,285.8	$	53.1	$	956.3	$	863.2	$	93.1	$	420.2	$	339.4	$	80.8
Operating Expenses:
Purchased Power and Transmission	850.6		523.5		327.1		360.9		313.7		47.2		226.7		125.8		100.9
Operations and Maintenance	160.3		157.1		3.2		166.1		164.9		1.2		67.8		59.6		8.2
Depreciation	92.2		87.3		4.9		90.5		89.0		1.5		34.1		31.3		2.8
Amortization of Regulatory   (Liabilities)/Assets, Net	(122.3)		169.7		(292.0)		22.8		29.3		(6.5)		(5.3)		26.8		(32.1)
Energy Efficiency Programs	32.6		35.4		(2.8)		86.2		80.3		5.9		10.2		8.7		1.5
Taxes Other Than Income Taxes	101.6		90.3		11.3		53.5		59.8		(6.3)		22.1		22.8		(0.7)
Total Operating Expenses	1,115.0		1,063.3		51.7		780.0		737.0		43.0		355.6		275.0		80.6
Operating Income	223.9		222.5		1.4		176.3		126.2		50.1		64.6		64.4		0.2
Interest Expense	45.2		40.6		4.6		44.9		38.2		6.7		17.5		13.6		3.9
Other Income, Net	14.9		19.6		(4.7)		39.9		29.2		10.7		5.7		7.5		(1.8)
Income Before Income Tax Expense	193.6		201.5		(7.9)		171.3		117.2		54.1		52.8		58.3		(5.5)
Income Tax Expense	45.2		48.5		(3.3)		37.5		24.5		13.0		12.5		12.7		(0.2)
Net Income	$	148.4	$	153.0	$	(4.6)	$	133.8	$	92.7	$	41.1	$	40.3	$	45.6	$	(5.3)

Operating Revenues

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

	For the Three Months Ended March 31,
	2023	2022	Percentage Decrease
CL&P	4,802	5,263	(8.8)	%
NSTAR Electric	5,496	5,710	(3.7)	%
PSNH	1,900	1,992	(4.6)	%

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 $53.1 million at CL&P, $93.1 million at NSTAR Electric, and $80.8 million at PSNH, for the three months ended March 31, 2023, as compared to the same period in 2022.

49

Base Distribution Revenues:

•CL&P's distribution revenues were flat.

•NSTAR Electric's distribution revenues increased $30.6 million due primarily to the result of a rate design change approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues (increase of $20.7 million in 2023, as compared to 2022) and a base distribution rate increase effective January 1, 2023 (increase of $9.9 million in 2023, as compared to 2022). As part of the 2022 NSTAR Electric rate case decision, certain customer rates changed from seasonal demand charges to a single annual demand charge effective January 1, 2023, resulting in a shift in the timing of revenues and earnings recognized quarterly in 2023, as compared to 2022, but with no impact on an annual basis. This rate design change will result in higher revenues in both the first and fourth quarters of 2023 of approximately $21 million, offset by lower revenues in the third quarter of 2023 of approximately $42 million, as compared to the same periods in 2022.

•PSNH's distribution revenues decreased $1.7 million due primarily to a decrease in sales volumes as a result of milder winter weather in the first quarter of 2023, as compared to the same period in 2022.

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 has no impact on earnings.  Revenues from certain of these cost tracking mechanisms also include certain incentives earned, return 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, retail transmission charges, energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), certain capital tracking mechanisms for infrastructure improvements, and additionally for NSTAR Electric, pension and PBOP benefits, net metering for distributed generation, and solar-related programs. 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.

Customers have the choice to purchase electricity from each Eversource electric utility or from a competitive third party supplier. For customers who have contracted separately with these competitive suppliers, revenue is not recorded for the sale of the electricity commodity, as the utility is acting as an agent on behalf of the third party supplier. For customers that choose to purchase electric generation from CL&P, NSTAR Electric or PSNH, each purchases power on behalf of, and is permitted to recover the related energy supply cost without mark-up from, its customers, and records offsetting amounts in revenues and purchased power and amortization expense related to this energy supply procurement. CL&P, NSTAR Electric and PSNH each remain as the distribution service provider for all customers and charge a regulated rate for distribution delivery service recorded in revenues.

Tracked distribution revenues increased/(decreased) for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

(Millions of Dollars)	CL&P		NSTAR Electric		PSNH
Retail Tariff Tracked Revenues:
Energy supply procurement	$	296.5	$	93.3	$	85.3
CL&P FMCC	(139.3)		—		—
Retail transmission	8.1		(13.2)		(14.2)
Other distribution tracking mechanisms	3.3		0.9		2.1
Wholesale Market Sales Revenue	(125.3)		(16.8)		(6.1)

The increase in energy supply procurement at CL&P, NSTAR Electric and PSNH was driven by higher average prices, partially offset by lower average supply-related sales volumes. Fluctuations in retail transmission revenues are driven by the recovery of the costs of our wholesale transmission business, such as those billed by ISO-NE and Local and Regional Network Service charges. For further information, see "Purchased Power and Transmission Expense" below.

The decrease in CL&P’s FMCC revenues was driven by a decrease in the retail Non-Bypassable Federally Mandated Congestion Charge (NBFMCC) rate, which reflects the impact of returning net benefits of higher wholesale market sales received in the ISO-NE market for long-term state approved energy contracts at CL&P, which are then credited back to customers through the retail NBFMCC rate. The average NBFMCC rate in the first quarter of 2023 was a credit to customers of $0.01300 per kWh, as compared to a charge to customers of $0.01460 per kWh in the first quarter of 2022. As a result of the CL&P RAM proceeding in Docket No. 22-01-03, CL&P reduced the NBFMCC rate effective September 1, 2022 from $0.01251 per kWh to $0.00000 per kWh. As part of a November 2022 rate relief plan, CL&P further reduced the NBFMCC rate effective January 1, 2023 to a credit of $0.01524 per kWh. These rate reductions returned to customers the net revenues generated by long-term state-approved energy contracts with the Millstone and Seabrook nuclear power plants. The NBFMCC rate will change to $0.00000 per kWh effective July 1, 2023.

The decrease in wholesale market sales revenue for the three months ended March 31, 2023, as compared to the same period in 2022, was due primarily to lower average electricity market prices received for wholesale sales at CL&P, NSTAR Electric and PSNH. ISO-NE average market prices received for CL&P’s wholesale sales decreased to an average price of $48.95 per MWh for the three months ended March 31, 2023, as compared to $105.35 per MWh for the three months ended March 31, 2022, driven primarily by lower natural gas prices in New England. CL&P’s volumes sold into the market were primarily from the sale of output generated by the Millstone PPA and Seabrook PPA that CL&P entered into in 2019, as required by regulation. CL&P sells the energy purchased from Millstone and Seabrook into the wholesale market and uses the proceeds from the energy sales to offset the contract costs. The net sales or net cost amount is refunded to, or recovered from, customers in the non-bypassable component of the CL&P FMCC rate.

50

Transmission Revenues: Transmission revenues increased $3.7 million at CL&P, $6.3 million at NSTAR Electric, and $13.4 million at PSNH for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure.

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 in rates charged to their customers. The impact of eliminations increased revenues by $6.0 million at CL&P and $1.8 million at PSNH and decreased revenues by $5.8 million at NSTAR Electric for the three months ended March 31, 2023, as compared to the same period in 2022.

Purchased Power and Transmission expense includes costs associated with purchasing electricity on behalf of CL&P, NSTAR Electric and PSNH's customers and the cost of energy purchase contracts, as required by regulation. These energy supply and other energy-related costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power and Transmission expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

(Millions of Dollars)	CL&P		NSTAR Electric		PSNH
Purchased Power Costs	$	305.5	$	66.3	$	108.1
Transmission Costs	15.4		(13.2)		(9.0)
Eliminations	6.2		(5.9)		1.8
Total Purchased Power and Transmission	$	327.1	$	47.2	$	100.9

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 and the cost of energy purchase contracts, as required by regulation.

•The increase at CL&P was due primarily to higher energy supply procurement costs resulting from higher average prices, partially offset by lower average supply-related sales volumes. The increase was also due to higher long-term contractual energy-related costs and higher net metering costs that are recovered in the non-bypassable component of the FMCC mechanism.

•The increase at NSTAR Electric was due primarily to higher energy supply procurement costs resulting from higher average prices, partially offset by lower average supply-related sales volumes. This was partially offset by a decrease in the cost deferral associated with long-term renewable contracts and a decrease in net metering costs.

•The increase at PSNH was due primarily to higher energy supply procurement costs resulting from higher average prices, partially offset by lower 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 increase in transmission costs at CL&P was due primarily to an increase resulting from the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers. This was partially offset by a decrease in costs billed by ISO-NE that support regional investments.

•The decrease in transmission costs at NSTAR Electric was due primarily to a decrease resulting from the retail transmission cost deferral and a decrease in costs billed by ISO-NE. This was partially offset by an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network.

•The decrease in transmission costs at PSNH was due primarily to a decrease resulting from the retail transmission cost deferral and a decrease in costs billed by ISO-NE. This was partially offset by an increase in Local Network Service charges.

Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs).  Operations and Maintenance expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

(Millions of Dollars)	CL&P		NSTAR Electric		PSNH
Base Electric Distribution (Non-Tracked Costs):
Operations-related expenses (including employee-related expenses, storm costs, vendor services, and vehicles)	$	4.4	$	0.1	$	3.6
Shared corporate costs (including computer software depreciation at Eversource Service)	3.0		5.4		1.1
General costs (including vendor services in corporate areas, insurance, fees and assessments)	2.6		3.3		1.2
Vegetation management	(5.0)		0.9		(1.2)
Other non-tracked operations and maintenance	(2.3)		(5.3)		(0.3)
Total Base Electric Distribution (Non-Tracked Costs)	2.7		4.4		4.4
Tracked Costs:
Transmission expenses	(1.6)		(0.7)		2.7
Other tracked operations and maintenance	2.1		(2.5)		1.1
Total Tracked Costs	0.5		(3.2)		3.8
Total Operations and Maintenance	$	3.2	$	1.2	$	8.2

51

Depreciation expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, for CL&P, NSTAR Electric and PSNH due to higher net plant in service balances. The increase at NSTAR Electric was partially offset by a decrease in approved depreciation rates as part of the rate case decision effective January 1, 2023.

Amortization of Regulatory (Liabilities)/Assets, Net expense includes the deferral of energy-related costs and other costs that are included in certain regulatory-approved cost tracking mechanisms. This deferral adjusts expense to match the corresponding revenues compared to the actual costs incurred. These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of certain costs as those costs are collected in rates. Amortization of Regulatory (Liabilities)/Assets, Net decreased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

•The decrease at CL&P was due primarily to the deferral adjustment of energy-related and other tracked costs that are included in the non-bypassable component of the FMCC mechanism, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The decrease in the FMCC mechanism was driven primarily by the CL&P November 2022 rate relief plan, which reduced the non-bypassable FMCC rate effective January 1, 2023. The reduction in the CL&P non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $286.6 million in the first quarter of 2023, as compared to the first quarter of 2022.

•The decrease at NSTAR Electric was due to the deferral adjustment of energy-related costs and other tracked costs, partially offset by an increase due to the amortization of historical exogenous property taxes that were approved for recovery effective January 1, 2023 in the November 2022 NSTAR Electric distribution rate case decision.

•The decrease at PSNH was due to the deferral adjustment of energy-related and other tracked 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/decreased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

•The decrease at CL&P was due to the deferral adjustment, which reflects actual costs of energy efficiency programs compared to the estimated amounts billed to customers, and the timing of the recovery of energy efficiency costs.

•The increases at NSTAR Electric and PSNH were due to the deferral adjustment and the timing of the recovery of energy efficiency costs.

Taxes Other Than Income Taxes increased/decreased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

•The increase at CL&P was related to higher gross earnings taxes.

•The decreases at NSTAR Electric and PSNH were due primarily to a decrease in property taxes due to lower mill rates.

Interest Expense increased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

•The increase at CL&P was due to higher interest on long-term debt ($3.8 million), an increase in interest expense on regulatory deferrals ($0.9 million), and higher interest on short-term notes payable ($0.6 million), partially offset by an increase in capitalized AFUDC related to debt funds ($0.7 million).

•The increase at NSTAR Electric was due to higher interest on long-term debt ($7.7 million) and an increase in interest expense on regulatory deferrals ($1.8 million), partially offset by lower interest resulting from the payment of withheld property taxes in the second quarter of 2022 ($1.6 million) and an increase in capitalized AFUDC related to debt funds ($1.4 million).

•The increase at PSNH was due to higher interest on long-term debt ($3.4 million), higher interest expense on regulatory deferrals ($0.9 million), and higher interest on short-term notes payable ($0.2 million), partially offset by an increase in capitalized AFUDC related to debt funds ($0.5 million) and a decrease in RRB interest expense ($0.3 million).

Other Income, Net increased/decreased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

•The decrease at CL&P was due primarily to a decrease related to pension, SERP and PBOP non-service income components ($6.4 million) and higher investment losses driven by market volatility ($0.2 million), partially offset by an increase in capitalized AFUDC related to equity funds ($1.3 million) and an increase in interest income primarily on regulatory deferrals ($0.6 million).

•The increase at NSTAR Electric was due primarily to an increase in interest income primarily on regulatory deferrals ($12.5 million), and an increase in capitalized AFUDC related to equity funds ($4.6 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($6.3 million).

•The decrease at PSNH was due primarily to a decrease related to pension, SERP and PBOP non-service income components ($2.4 million) and lower investment income driven by market volatility ($0.3 million), partially offset by an increase in interest income primarily on regulatory deferrals ($0.6 million) and an increase in capitalized AFUDC related to equity funds ($0.3 million).

52

Income Tax Expense increased/decreased for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to the following:

•The decrease at CL&P was due primarily to lower pre-tax earnings ($1.7 million), lower state taxes ($1.4 million), an increase in amortization of EDIT ($0.2 million), and a decrease in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.9 million), partially offset by lower share-based payment excess tax benefits ($0.9 million).

•The increase at NSTAR Electric was due primarily to an increase in pre-tax earnings ($11.4 million), higher state taxes ($3.0 million), lower share-based payment excess tax benefits ($1.0 million), and a decrease in amortization of EDIT ($0.6 million), partially offset by a decrease in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($3.0 million).

•The decrease at PSNH was due primarily to lower pre-tax earnings ($1.2 million) and lower state taxes ($0.4 million), partially offset by a decrease in amortization of EDIT ($0.5 million) and an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.9 million).    

EARNINGS SUMMARY

CL&P's earnings decreased $4.6 million for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to higher property and other tax expense, higher pension plan expense, higher operations and maintenance expense, higher depreciation expense, and higher interest expense. The earnings decrease was partially offset by higher earnings from its capital tracking mechanism due to increased electric system improvements.

NSTAR Electric's earnings increased $41.1 million for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to higher revenues as a result of the rate design change approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues and the base distribution rate increase effective January 1, 2023. Earnings were also favorably impacted by an increase in interest income primarily on regulatory deferrals and an increase in transmission earnings driven by a higher transmission rate base, partially offset by higher operations and maintenance expense.

PSNH's earnings decreased $5.3 million for the three months ended March 31, 2023, as compared to the same period in 2022, due primarily to higher operations and maintenance expense, higher interest expense, lower sales volumes, and higher pension plan expense. The earnings decrease was partially offset by an increase in transmission earnings driven by a higher transmission rate base.

LIQUIDITY

Cash Flows: CL&P had cash flows used in operating activities of $73.6 million for the three months ended March 31, 2023, as compared to cash flows provided by operating activities of $135.3 million in the same period of 2022. The decrease in operating cash flows was due primarily to an increase in regulatory under-recoveries driven primarily by the timing of collections for the non-bypassable FMCC and other regulatory tracking mechanisms and the timing of cash payments made on our accounts payable. In 2023, CL&P increased the flow back to customers of net revenues generated by long-term state-approved energy contracts by providing these credits to customers through the non-bypassable FMCC retail rate. The reduction in the non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $286.6 million in the first quarter of 2023, as compared to the first quarter of 2022, and is presented as a cash outflow in Amortization on the statement of cash flows. The impact of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Liabilities/Assets on the statements of cash flows. These unfavorable impacts were partially offset by a $64.6 million decrease in cash payments for storm costs, the absence in 2023 of $58.4 million of customer credits distributed in 2022 as a result of the October 2021 settlement agreement and the 2021 storm performance penalty for CL&P’s response to Tropical Storm Isaias, the timing of cash collections on our accounts receivable, a $30.0 million increase in income tax refunds received in 2023, as compared to 2022, and the timing of other working capital items.

Effective July 1, 2023, CL&P’s non-bypassable FMCC retail rate will change to $0.00000 per kWh, as compared to a credit of $0.01524 per kWh from January 1, 2023 to June 30, 2023. The increase in the retail rate will result in higher cash collections in the second half of 2023, as compared to the first half of 2023.

NSTAR Electric had cash flows provided by operating activities of $140.8 million for the three months ended March 31, 2023, as compared to $189.9 million in the same period of 2022. The decrease in operating cash flows was due primarily to the timing of cash collections on our accounts receivable, an increase in regulatory under-recoveries driven by the timing of collections for regulatory tracking mechanisms, a $35.4 million decrease in income tax refunds received in 2023, as compared to 2022, and the timing of other working capital items. The impact of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Assets on the statements of cash flows. These unfavorable impacts were partially offset by the timing of cash payments made on our accounts payable, a $35.5 million decrease in cash payments for storm costs, and the absence in 2023 of pension contributions of $5.0 million made in 2022.

PSNH had cash flows used in operating activities of $72.9 million for the three months ended March 31, 2023, as compared to cash flows provided by operating activities of $58.1 million in the same period of 2022.  The decrease in operating cash flows was due primarily to an increase in regulatory under-recoveries driven by the timing of collections for regulatory tracking mechanisms, primarily the energy supply tracking mechanism resulted in an unfavorable impact of $59.8 million, and a $28.9 million increase in cash payments for storm costs. The impact of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Liabilities/Assets on the statements of cash flows. These unfavorable impacts were partially offset by a $21.9 million increase in income tax refunds received in 2023, as compared to 2022, the timing of cash collections on our accounts receivable, and the timing of cash payments made on our accounts payable.

53

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.

ITEM 3.     QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Market Risk Information

Commodity Price Risk Management:  Our regulated companies enter into energy contracts to serve our customers, and the economic impacts of those contracts are passed on to our customers. Accordingly, the regulated companies have no exposure to loss of future earnings or fair values due to these market risk-sensitive instruments.  Eversource's Energy Supply Risk Committee, comprised of senior officers, reviews and approves all large-scale energy related transactions entered into by its regulated companies.

Other Risk Management Activities

Interest Rate Risk Management:  We manage our interest rate risk exposure in accordance with our written policies and procedures by maintaining a mix of fixed and variable rate long-term debt.

Credit Risk Management:  Credit risk relates to the risk of loss that we would incur as a result of non-performance by counterparties pursuant to the terms of our contractual obligations.  We serve a wide variety of customers and transact with suppliers that include IPPs, industrial companies, natural gas and electric utilities, oil and 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 March 31, 2023, our regulated companies held collateral (letters of credit or cash) of $17.0 million from counterparties related to our standard service contracts.  As of March 31, 2023, Eversource had $36.1 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 2022 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 2022 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 March 31, 2023 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 March 31, 2023 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.

54

PART II. OTHER INFORMATION

ITEM 1.    LEGAL PROCEEDINGS

We are parties to various legal proceedings.  We have disclosed certain legal proceedings in Part I, Item 3, "Legal Proceedings," and elsewhere in our 2022 Form 10-K.  These disclosures are incorporated herein by reference.  There have been no material legal proceedings identified and no material changes with regard to the legal proceedings previously disclosed in our 2022 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 2022 Form 10-K, which risk factors are incorporated herein by reference. These risk factors should be considered carefully in evaluating our risk profile. There have been no additional risk factors identified and no material changes with regard to the risk factors previously disclosed in our 2022 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)
January 1 - January 31, 2023	46	$	81.17	—	—
February 1 - February 28, 2023	—	—		—	—
March 1 - March 31, 2023	2,479	78.29		—	—
Total	2,525	$	78.35	—	—

55

ITEM 6.    EXHIBITS

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

	Exhibit No.	Description
	Listing of Exhibits (Eversource)
*	4	Eighteenth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company, N.A., as Trustee, dated as of March 1, 2023, relating to $750 million aggregate principal amount of its 5.45% Senior Notes, Series Z, Due 2028 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed March 6, 2023, 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)
	31	Certification by the Interim Chairman and Chief Executive Officer 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 Interim Chairman and Chief Executive Officer 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)
	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 March 31, 2023, formatted in Inline XBRL

56

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
May 5, 2023	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE

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

	THE CONNECTICUT LIGHT AND POWER COMPANY
May 5, 2023	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE

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

	NSTAR ELECTRIC COMPANY
May 5, 2023	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE

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

	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
May 5, 2023	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

57

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Joseph R. Nolan, Jr., certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  May 5, 2023

/s/	Joseph R. Nolan, Jr.
	Joseph R. Nolan, Jr.
	Chairman of the Board, President and Chief Executive Officer
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, John M. Moreira, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  May 5, 2023

/s/	John M. Moreira
	John M. Moreira
	Executive Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of Eversource Energy (the registrant) for the period ending March 31, 2023 as filed with the Securities and Exchange Commission (the Report), we, Joseph R. Nolan, Jr., Chairman of the Board, President and Chief Executive Officer of the registrant, and John M. Moreira, Executive Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/	Joseph R. Nolan, Jr.
	Joseph R. Nolan, Jr.
	Chairman of the Board, President and Chief Executive Officer

/s/	John M. Moreira
	John M. Moreira
	Executive Vice President, Chief Financial Officer and Treasurer

Date:  May 5, 2023

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, James W. Hunt, III, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  May 5, 2023

/s/	James W. Hunt, III
	James W. Hunt, III
	Interim Chairman and Chief Executive Officer
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, John M. Moreira, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  May 5, 2023

/s/	John M. Moreira
	John M. Moreira
	Executive Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of The Connecticut Light and Power Company (the registrant) for the period ending March 31, 2023 as filed with the Securities and Exchange Commission (the Report), we, James W. Hunt, III, Interim Chairman and Chief Executive Officer of the registrant, and John M. Moreira, Executive Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/	James W. Hunt, III
	James W. Hunt, III
	Interim Chairman and Chief Executive Officer

/s/	John M. Moreira
	John M. Moreira
	Executive Vice President, Chief Financial Officer and Treasurer

Date:  May 5, 2023

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Joseph R. Nolan, Jr., certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  May 5, 2023

/s/	Joseph R. Nolan, Jr.
	Joseph R. Nolan, Jr.
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, John M. Moreira, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  May 5, 2023

/s/	John M. Moreira
	John M. Moreira
	Executive Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of NSTAR Electric Company (the registrant) for the period ending March 31, 2023 as filed with the Securities and Exchange Commission (the Report), we, Joseph R. Nolan, Jr., Chairman of the registrant, and John M. Moreira, Executive Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/	Joseph R. Nolan, Jr.
	Joseph R. Nolan, Jr.
	Chairman

/s/	John M. Moreira
	John M. Moreira
	Executive Vice President, Chief Financial Officer and Treasurer

Date:  May 5, 2023

EX-31

Exhibit 31

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Joseph R. Nolan, Jr., certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  May 5, 2023

/s/	Joseph R. Nolan, Jr.
	Joseph R. Nolan, Jr.
	Chairman
	(Principal Executive Officer)

EX-31.1

Exhibit 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, John M. Moreira, certify that:

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

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

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

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

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

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

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

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

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

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

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

Date:  May 5, 2023

/s/	John M. Moreira
	John M. Moreira
	Executive Vice President, Chief Financial Officer and Treasurer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with this Quarterly Report on Form 10-Q of Public Service Company of New Hampshire (the registrant) for the period ending March 31, 2023 as filed with the Securities and Exchange Commission (the Report), we, Joseph R. Nolan, Jr., Chairman of the registrant, and John M. Moreira, Executive Vice President, Chief Financial Officer and Treasurer of the registrant, certify, pursuant to 18 U.S.C. Sec. 1350, as adopted pursuant to Sec. 906 of the Sarbanes-Oxley Act of 2002, that:

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

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

/s/	Joseph R. Nolan, Jr.
	Joseph R. Nolan, Jr.
	Chairman

/s/	John M. Moreira
	John M. Moreira
	Executive Vice President, Chief Financial Officer and Treasurer

Date:  May 5, 2023

XML

COVER PAGE - shares	3 Months Ended
	Mar. 31, 2023	Apr. 30, 2023
Document And Entity [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2023
Document Transition Report	false
Entity Registrant Name	EVERSOURCE ENERGY
Entity Incorporation, State or Country Code	MA
Entity Address, Address Line One	300 Cadwell Drive
Entity Address, City or Town	Springfield
Entity Address, State or Province	MA
Entity Address, Postal Zip Code	01104
City Area Code	800
Local Phone Number	286-5000
Entity File Number	001-05324
Entity Tax Identification Number	04-2147929
Title of 12(b) Security	Common Shares, $5.00 par value per share
Trading Symbol	ES
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Smaller Reporting Company	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		348,841,840
Entity Central Index Key	0000072741
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q1
Amendment Flag	false
The Connecticut Light and Power Company
Document And Entity [Line Items]
Entity Registrant Name	THE CONNECTICUT LIGHT AND POWER COMPANY
Entity Incorporation, State or Country Code	CT
Entity Address, Address Line One	107 Selden Street
Entity Address, City or Town	Berlin
Entity Address, State or Province	CT
Entity Address, Postal Zip Code	06037-1616
City Area Code	800
Local Phone Number	286-5000
Entity File Number	000-00404
Entity Tax Identification Number	06-0303850
Entity Filer Category	Non-accelerated Filer
Entity Smaller Reporting Company	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		6,035,205
Entity Central Index Key	0000023426
Current Fiscal Year End Date	--12-31
NSTAR Electric Company
Document And Entity [Line Items]
Entity Registrant Name	NSTAR ELECTRIC COMPANY
Entity Incorporation, State or Country Code	MA
Entity Address, Address Line One	800 Boylston Street
Entity Address, City or Town	Boston
Entity Address, State or Province	MA
Entity Address, Postal Zip Code	02199
City Area Code	800
Local Phone Number	286-5000
Entity File Number	001-02301
Entity Tax Identification Number	04-1278810
Entity Filer Category	Non-accelerated Filer
Entity Smaller Reporting Company	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		200
Entity Central Index Key	0000013372
Current Fiscal Year End Date	--12-31
Public Service Company of New Hampshire
Document And Entity [Line Items]
Entity Registrant Name	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
Entity Incorporation, State or Country Code	NH
Entity Address, Address Line One	Energy Park
Entity Address, Address Line Two	780 North Commercial Street
Entity Address, City or Town	Manchester
Entity Address, State or Province	NH
Entity Address, Postal Zip Code	03101-1134
City Area Code	800
Local Phone Number	286-5000
Entity File Number	001-06392
Entity Tax Identification Number	02-0181050
Entity Filer Category	Non-accelerated Filer
Entity Smaller Reporting Company	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)		301
Entity Central Index Key	0000315256
Current Fiscal Year End Date	--12-31

XML

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash	$ 35,975	$ 47,597
Cash Equivalents	0	327,006
Receivables, Net (net of allowance for uncollectible accounts)	1,660,076	1,517,138
Unbilled Revenues	216,715	238,968
Materials, Supplies, Natural Gas and REC Inventory	423,343	374,395
Regulatory Assets	1,332,028	1,335,491
Prepayments and Other Current Assets	468,292	382,603
Total Current Assets	4,136,429	4,223,198
Property, Plant and Equipment, Net	36,744,855	36,112,820
Deferred Debits and Other Assets:
Regulatory Assets	4,407,875	4,242,794
Goodwill	4,522,632	4,522,632
Investments in Unconsolidated Affiliates	2,302,880	2,176,080
Prepaid Pension and PBOP	1,097,814	1,045,524
Marketable Securities	332,050	366,508
Other Long-Term Assets	560,632	541,344
Total Deferred Debits and Other Assets	13,223,883	12,894,882
Total Assets	54,105,167	53,230,900
Current Liabilities:
Notes Payable	1,195,500	1,442,200
Long-Term Debt – Current Portion	1,615,461	1,320,129
Rate Reduction Bonds – Current Portion	43,210	43,210
Accounts Payable	1,821,911	2,113,905
Regulatory Liabilities	650,538	890,786
Other Current Liabilities	1,078,421	989,053
Total Current Liabilities	6,405,041	6,799,283
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	5,239,443	5,067,902
Regulatory Liabilities	3,974,374	3,930,305
Derivative Liabilities	124,281	143,929
Asset Retirement Obligations	500,695	502,713
Accrued Pension, SERP and PBOP	120,200	135,473
Other Long-Term Liabilities	884,717	888,081
Total Deferred Credits and Other Liabilities	10,843,710	10,668,403
Long-Term Debt	20,562,588	19,723,994
Rate Reduction Bonds	388,887	410,492
Noncontrolling Interest – Preferred Stock of Subsidiaries	155,570	155,570
Common Shareholders' Equity:
Common Shares	1,799,920	1,799,920
Capital Surplus, Paid In	8,412,085	8,401,731
Retained Earnings	5,782,958	5,527,153
Accumulated Other Comprehensive Loss	(36,191)	(39,421)
Treasury Stock	(209,401)	(216,225)
Common Shareholders' Equity	15,749,371	15,473,158
Commitments and Contingencies
Total Liabilities and Capitalization	$ 54,105,167	$ 53,230,900

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Allowance for uncollectible accounts	$ 535,114	$ 486,297

XML

CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Income Statement [Abstract]
Operating Revenues	$ 3,795,643	$ 3,471,310
Operating Expenses:
Purchased Power, Purchased Natural Gas and Transmission	1,903,246	1,389,696
Operations and Maintenance	454,562	472,433
Depreciation	312,955	289,330
Amortization	(76,059)	236,948
Energy Efficiency Programs	222,952	199,484
Taxes Other Than Income Taxes	228,414	220,364
Total Operating Expenses	3,046,070	2,808,255
Operating Income/(Loss)	749,573	663,055
Interest Expense	194,543	153,245
Other Income, Net	88,981	71,561
Income Before Income Tax Expense	644,011	581,371
Income Tax Expense	150,972	136,045
Net Income	493,039	445,326
Net Income Attributable to Noncontrolling Interests	1,880	1,880
Net Income Attributable to Common Shareholders	$ 491,159	$ 443,446
Basic EPS (in dollars per share)	$ 1.41	$ 1.28
Diluted EPS (in dollars per share)	$ 1.41	$ 1.28
Weighted Average Common Shares Outstanding:
Basic (in shares)	349,217,147	345,156,346
Diluted (in shares)	349,612,013	345,661,133

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Comprehensive Income [Abstract]
Net Income	$ 493,039	$ 445,326
Other Comprehensive Income, Net of Tax:
Qualified Cash Flow Hedging Instruments	5	5
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,254	(817)
Changes in Funded Status of Pension, SERP and PBOP Benefit Plans	1,971	1,516
Other Comprehensive Income (Loss), Net of Tax	3,230	704
Comprehensive Income Attributable to Noncontrolling Interests	(1,880)	(1,880)
Comprehensive Income Attributable to Common Shareholders	$ 494,389	$ 444,150

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY - USD ($) $ in Thousands	Total	Common Shares	Capital Surplus, Paid In	Retained Earnings	Accumulated Other Comprehensive Loss	Treasury Stock
Balance (in shares) at Dec. 31, 2021		344,403,196
Balance at Dec. 31, 2021	$ 14,599,844	$ 1,789,092	$ 8,098,514	$ 5,005,391	$ (42,275)	$ (250,878)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	445,326			445,326
Dividends on Common Stock	(219,768)			(219,768)
Dividends on Preferred Stock	(1,880)			(1,880)
Long-Term Incentive Plan Activity	(16,538)		(16,538)
Issuance of Treasury Shares (in shares)		447,076
Issuance of Treasury Shares	29,002		20,642			8,360
Other Comprehensive Income, Net of Tax	704				704
Balance (in shares) at Mar. 31, 2022		344,850,272
Balance at Mar. 31, 2022	$ 14,836,690	$ 1,789,092	8,102,618	5,229,069	(41,571)	(242,518)
Balance (in shares) at Dec. 31, 2022	348,443,855	348,443,855
Balance at Dec. 31, 2022	$ 15,473,158	$ 1,799,920	8,401,731	5,527,153	(39,421)	(216,225)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	493,039			493,039
Dividends on Common Stock	(235,354)			(235,354)
Dividends on Preferred Stock	(1,880)			(1,880)
Long-Term Incentive Plan Activity	(13,141)		(13,141)
Issuance of Treasury Shares (in shares)		364,227
Issuance of Treasury Shares	30,319		23,495			6,824
Other Comprehensive Income, Net of Tax	$ 3,230				3,230
Balance (in shares) at Mar. 31, 2023	348,808,082	348,808,082
Balance at Mar. 31, 2023	$ 15,749,371	$ 1,799,920	$ 8,412,085	$ 5,782,958	$ (36,191)	$ (209,401)

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Statement of Stockholders' Equity [Abstract]
Dividends on Common Shares (in dollars per share)	$ 0.675	$ 0.6375

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net Income	$ 493,039	$ 445,326
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	312,955	289,330
Deferred Income Taxes	149,197	67,557
Uncollectible Expense	22,821	17,135
Pension, SERP and PBOP Income, Net	(24,563)	(40,642)
Pension Contributions	(1,100)	(26,100)
Regulatory Under Recoveries, Net	(158,964)	(107,767)
Customer Credits at CL&P related to PURA Settlement Agreement and Storm Performance Penalty	0	(58,412)
Amortization	(76,059)	236,948
Cost of Removal Expenditures	(70,514)	(61,660)
Other	(54,486)	(21,409)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(225,609)	(291,723)
Taxes Receivable/Accrued, Net	284	56,519
Accounts Payable	(258,476)	(68,909)
Other Current Assets and Liabilities, Net	(39,368)	(64,253)
Net Cash Flows (Used In)/Provided by Operating Activities	69,157	371,940
Investing Activities:
Investments in Property, Plant and Equipment	(977,144)	(764,594)
Proceeds from Sales of Marketable Securities	64,307	90,409
Purchases of Marketable Securities	(56,508)	(76,182)
Investments in Unconsolidated Affiliates	(87,845)	(113,856)
Other Investing Activities	5,640	5,976
Net Cash Flows Used in Investing Activities	(1,051,550)	(858,247)
Financing Activities:
Cash Dividends on Common Shares	(229,405)	(213,890)
Cash Dividends on Preferred Stock	(1,880)	(1,880)
(Decrease)/Increase in Notes Payable	(246,700)	163,350
Repayment of Rate Reduction Bonds	(21,605)	(21,605)
Issuance of Long-Term Debt	1,550,000	1,300,000
Retirement of Long-Term Debt	(400,000)	(770,000)
Other Financing Activities	(27,002)	(26,087)
Net Cash Flows (Used in)/Provided by Financing Activities	623,408	429,888
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(358,985)	(56,419)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	521,752	221,008
Cash and Restricted Cash - End of Period	$ 162,767	$ 164,589

XML

THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash	$ 35,975	$ 47,597
Receivables, Net (net of allowance for uncollectible accounts)	1,660,076	1,517,138
Unbilled Revenues	216,715	238,968
Materials, Supplies, Natural Gas and REC Inventory	423,343	374,395
Regulatory Assets	1,332,028	1,335,491
Prepayments and Other Current Assets	468,292	382,603
Total Current Assets	4,136,429	4,223,198
Property, Plant and Equipment, Net	36,744,855	36,112,820
Deferred Debits and Other Assets:
Total Long-Term Regulatory Assets	4,407,875	4,242,794
Prepaid Pension	1,097,814	1,045,524
Other Long-Term Assets	560,632	541,344
Total Deferred Debits and Other Assets	13,223,883	12,894,882
Total Assets	54,105,167	53,230,900
Current Liabilities:
Accounts Payable	1,821,911	2,113,905
Regulatory Liabilities	650,538	890,786
Other Current Liabilities	1,078,421	989,053
Total Current Liabilities	6,405,041	6,799,283
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	5,239,443	5,067,902
Regulatory Liabilities	3,974,374	3,930,305
Derivative Liabilities	124,281	143,929
Other Long-Term Liabilities	884,717	888,081
Total Deferred Credits and Other Liabilities	10,843,710	10,668,403
Long-Term Debt	20,562,588	19,723,994
Noncontrolling Interest – Preferred Stock of Subsidiaries	155,570	155,570
Common Shareholders' Equity:
Capital Surplus, Paid In	8,412,085	8,401,731
Retained Earnings	5,782,958	5,527,153
Accumulated Other Comprehensive Income	(36,191)	(39,421)
Common Shareholders' Equity	15,749,371	15,473,158
Commitments and Contingencies
Total Liabilities and Capitalization	54,105,167	53,230,900
The Connecticut Light and Power Company
Current Assets:
Cash	9,340	11,312
Receivables, Net (net of allowance for uncollectible accounts)	633,048	612,052
Accounts Receivable from Affiliated Companies	69,095	46,439
Unbilled Revenues	54,048	59,363
Materials, Supplies, Natural Gas and REC Inventory	103,987	88,157
Taxes Receivable	26,723	65,785
Regulatory Assets	356,468	314,089
Prepayments and Other Current Assets	93,078	62,524
Total Current Assets	1,345,787	1,259,721
Property, Plant and Equipment, Net	11,630,278	11,467,024
Deferred Debits and Other Assets:
Total Long-Term Regulatory Assets	1,639,960	1,593,693
Prepaid Pension	155,856	147,914
Other Long-Term Assets	302,817	290,444
Total Deferred Debits and Other Assets	2,098,633	2,032,051
Total Assets	15,074,698	14,758,796
Current Liabilities:
Notes Payable to Eversource Parent	318,000	0
Accounts Payable	622,024	710,500
Accounts Payable to Affiliated Companies	141,792	136,277
Regulatory Liabilities	124,640	336,048
Derivative Liabilities	85,105	81,588
Other Current Liabilities	205,692	163,875
Total Current Liabilities	1,497,253	1,428,288
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,740,504	1,640,034
Regulatory Liabilities	1,277,281	1,263,396
Derivative Liabilities	124,281	143,929
Other Long-Term Liabilities	160,104	166,081
Total Deferred Credits and Other Liabilities	3,302,170	3,213,440
Long-Term Debt	4,310,233	4,216,488
Noncontrolling Interest – Preferred Stock of Subsidiaries	116,200	116,200
Common Shareholders' Equity:
Common Shares	60,352	60,352
Capital Surplus, Paid In	3,260,765	3,260,765
Retained Earnings	2,527,520	2,463,094
Accumulated Other Comprehensive Income	205	169
Common Shareholders' Equity	5,848,842	5,784,380
Commitments and Contingencies
Total Liabilities and Capitalization	$ 15,074,698	$ 14,758,796

XML

THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Allowance for uncollectible accounts	$ 535,114	$ 486,297
The Connecticut Light and Power Company
Allowance for uncollectible accounts	$ 253,376	$ 225,320

XML

THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED STATEMENTS OF INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues	$ 3,795,643	$ 3,471,310
Operating Expenses:
Purchased Power and Transmission	1,903,246	1,389,696
Operations and Maintenance	454,562	472,433
Depreciation	312,955	289,330
Energy Efficiency Programs	222,952	199,484
Taxes Other Than Income Taxes	228,414	220,364
Total Operating Expenses	3,046,070	2,808,255
Operating Income/(Loss)	749,573	663,055
Interest Expense	194,543	153,245
Other Income, Net	88,981	71,561
Income Before Income Tax Expense	644,011	581,371
Income Tax Expense	150,972	136,045
Net Income	493,039	445,326
The Connecticut Light and Power Company
Operating Revenues	1,338,905	1,285,831
Operating Expenses:
Purchased Power and Transmission	850,564	523,463
Operations and Maintenance	160,316	157,061
Depreciation	92,237	87,265
Amortization of Regulatory (Liabilities)/Assets, Net	(122,315)	169,749
Energy Efficiency Programs	32,646	35,397
Taxes Other Than Income Taxes	101,584	90,373
Total Operating Expenses	1,115,032	1,063,308
Operating Income/(Loss)	223,873	222,523
Interest Expense	45,201	40,586
Other Income, Net	14,937	19,564
Income Before Income Tax Expense	193,609	201,501
Income Tax Expense	45,193	48,524
Net Income	$ 148,416	$ 152,977

XML

THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net Income	$ 493,039	$ 445,326
Other Comprehensive Income/(Loss), Net of Tax:
Qualified Cash Flow Hedging Instruments	5	5
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,254	(817)
Other Comprehensive Income (Loss), Net of Tax	3,230	704
Comprehensive Income Attributable to Common Shareholders	494,389	444,150
The Connecticut Light and Power Company
Net Income	148,416	152,977
Other Comprehensive Income/(Loss), Net of Tax:
Qualified Cash Flow Hedging Instruments	(7)	(7)
Changes in Unrealized Gains/(Losses) on Marketable Securities	43	(28)
Other Comprehensive Income (Loss), Net of Tax	36	(35)
Comprehensive Income Attributable to Common Shareholders	$ 148,452	$ 152,942

XML

THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY - USD ($) $ in Thousands	Total	Common Stock	Capital Surplus, Paid In	Retained Earnings	Accumulated Other Comprehensive Loss	The Connecticut Light and Power Company	The Connecticut Light and Power Company Common Stock	The Connecticut Light and Power Company Capital Surplus, Paid In	The Connecticut Light and Power Company Retained Earnings	The Connecticut Light and Power Company Accumulated Other Comprehensive Loss
Balance (in shares) at Dec. 31, 2021		344,403,196					6,035,205
Balance at Dec. 31, 2021	$ 14,599,844	$ 1,789,092	$ 8,098,514	$ 5,005,391	$ (42,275)	$ 5,299,501	$ 60,352	$ 3,010,765	$ 2,228,133	$ 251
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	445,326			445,326		152,977			152,977
Dividends on Preferred Stock	(1,880)			(1,880)		(1,390)			(1,390)
Dividends on Common Stock	(219,768)			(219,768)		(73,100)			(73,100)
Capital Contributions from Eversource Parent						100,000		100,000
Other Comprehensive Income, Net of Tax	704				704	(35)				(35)
Balance (in shares) at Mar. 31, 2022		344,850,272					6,035,205
Balance at Mar. 31, 2022	$ 14,836,690	$ 1,789,092	8,102,618	5,229,069	(41,571)	5,477,953	$ 60,352	3,110,765	2,306,620	216
Balance (in shares) at Dec. 31, 2022	348,443,855	348,443,855					6,035,205
Balance at Dec. 31, 2022	$ 15,473,158	$ 1,799,920	8,401,731	5,527,153	(39,421)	5,784,380	$ 60,352	3,260,765	2,463,094	169
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	493,039			493,039		148,416			148,416
Dividends on Preferred Stock	(1,880)			(1,880)		(1,390)			(1,390)
Dividends on Common Stock	(235,354)			(235,354)		(82,600)			(82,600)
Other Comprehensive Income, Net of Tax	$ 3,230				3,230	36				36
Balance (in shares) at Mar. 31, 2023	348,808,082	348,808,082					6,035,205
Balance at Mar. 31, 2023	$ 15,749,371	$ 1,799,920	$ 8,412,085	$ 5,782,958	$ (36,191)	$ 5,848,842	$ 60,352	$ 3,260,765	$ 2,527,520	$ 205

XML

THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net Income	$ 493,039	$ 445,326
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	312,955	289,330
Deferred Income Taxes	149,197	67,557
Uncollectible Expense	22,821	17,135
Pension, SERP, and PBOP Income, Net	(24,563)	(40,642)
Regulatory Under Recoveries, Net	(158,964)	(107,767)
Customer Credits at CL&P related to PURA Settlement Agreement and Storm Performance Penalty	0	(58,412)
Cost of Removal Expenditures	(70,514)	(61,660)
Other	(54,486)	(21,409)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(225,609)	(291,723)
Taxes Receivable/Accrued, Net	284	56,519
Accounts Payable	(258,476)	(68,909)
Other Current Assets and Liabilities, Net	(39,368)	(64,253)
Net Cash Flows (Used In)/Provided by Operating Activities	69,157	371,940
Investing Activities:
Investments in Property, Plant and Equipment	(977,144)	(764,594)
Other Investing Activities	5,640	5,976
Net Cash Flows Used in Investing Activities	(1,051,550)	(858,247)
Financing Activities:
Cash Dividends on Common Shares	(229,405)	(213,890)
Cash Dividends on Preferred Stock	(1,880)	(1,880)
Issuance of Long-Term Debt	1,550,000	1,300,000
Retirement of Long-Term Debt	(400,000)	(770,000)
(Decrease)/Increase in Notes Payable to Eversource Parent	(246,700)	163,350
Other Financing Activities	(27,002)	(26,087)
Net Cash Flows (Used in)/Provided by Financing Activities	623,408	429,888
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(358,985)	(56,419)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	521,752	221,008
Cash and Restricted Cash - End of Period	162,767	164,589
The Connecticut Light and Power Company
Operating Activities:
Net Income	148,416	152,977
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	92,237	87,265
Deferred Income Taxes	94,267	19,627
Uncollectible Expense	3,876	3,776
Pension, SERP, and PBOP Income, Net	(4,461)	(7,330)
Regulatory Under Recoveries, Net	(110,114)	(162,474)
Customer Credits at CL&P related to PURA Settlement Agreement and Storm Performance Penalty	0	(58,412)
Amortization of Regulatory (Liabilities)/Assets, Net	(122,315)	169,749
Cost of Removal Expenditures	(13,011)	(16,684)
Other	(13,964)	(9,357)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(76,482)	(125,429)
Taxes Receivable/Accrued, Net	52,261	67,708
Accounts Payable	(110,926)	38,010
Other Current Assets and Liabilities, Net	(13,412)	(24,143)
Net Cash Flows (Used In)/Provided by Operating Activities	(73,628)	135,283
Investing Activities:
Investments in Property, Plant and Equipment	(255,905)	(205,343)
Other Investing Activities	126	346
Net Cash Flows Used in Investing Activities	(255,779)	(204,997)
Financing Activities:
Cash Dividends on Common Shares	(82,600)	(73,100)
Cash Dividends on Preferred Stock	(1,390)	(1,390)
Capital Contributions from Eversource Parent	0	100,000
Issuance of Long-Term Debt	500,000	0
Retirement of Long-Term Debt	(400,000)	0
(Decrease)/Increase in Notes Payable to Eversource Parent	318,000	0
Other Financing Activities	(6,521)	0
Net Cash Flows (Used in)/Provided by Financing Activities	327,489	25,510
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(1,918)	(44,204)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	20,327	74,788
Cash and Restricted Cash - End of Period	$ 18,409	$ 30,584

XML

NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash	$ 35,975	$ 47,597
Cash Equivalents	0	327,006
Receivables, Net (net of allowance for uncollectible accounts)	1,660,076	1,517,138
Unbilled Revenues	216,715	238,968
Materials, Supplies, Natural Gas and REC Inventory	423,343	374,395
Regulatory Assets	1,332,028	1,335,491
Prepayments and Other Current Assets	468,292	382,603
Total Current Assets	4,136,429	4,223,198
Property, Plant and Equipment, Net	36,744,855	36,112,820
Deferred Debits and Other Assets:
Total Long-Term Regulatory Assets	4,407,875	4,242,794
Prepaid Pension and PBOP	1,097,814	1,045,524
Other Long-Term Assets	560,632	541,344
Total Deferred Debits and Other Assets	13,223,883	12,894,882
Total Assets	54,105,167	53,230,900
Current Liabilities:
Notes Payable	1,195,500	1,442,200
Long-Term Debt – Current Portion	1,615,461	1,320,129
Accounts Payable	1,821,911	2,113,905
Regulatory Liabilities	650,538	890,786
Other Current Liabilities	1,078,421	989,053
Total Current Liabilities	6,405,041	6,799,283
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	5,239,443	5,067,902
Regulatory Liabilities	3,974,374	3,930,305
Other Long-Term Liabilities	884,717	888,081
Total Deferred Credits and Other Liabilities	10,843,710	10,668,403
Long-Term Debt	20,562,588	19,723,994
Preferred Stock Not Subject to Mandatory Redemption	155,570	155,570
Common Shareholders' Equity:
Capital Surplus, Paid In	8,412,085	8,401,731
Retained Earnings	5,782,958	5,527,153
Accumulated Other Comprehensive Income	(36,191)	(39,421)
Common Shareholders' Equity	15,749,371	15,473,158
Commitments and Contingencies
Total Liabilities and Capitalization	54,105,167	53,230,900
NSTAR Electric Company
Current Assets:
Cash	618	738
Cash Equivalents	0	327,006
Receivables, Net (net of allowance for uncollectible accounts)	500,985	453,371
Accounts Receivable from Affiliated Companies	59,062	35,196
Unbilled Revenues	43,091	39,680
Materials, Supplies, Natural Gas and REC Inventory	190,301	138,352
Regulatory Assets	559,758	492,759
Prepayments and Other Current Assets	62,149	71,276
Total Current Assets	1,415,964	1,558,378
Property, Plant and Equipment, Net	11,819,012	11,626,968
Deferred Debits and Other Assets:
Total Long-Term Regulatory Assets	1,263,534	1,221,619
Prepaid Pension and PBOP	596,214	576,809
Other Long-Term Assets	118,185	111,846
Total Deferred Debits and Other Assets	1,977,933	1,910,274
Total Assets	15,212,909	15,095,620
Current Liabilities:
Notes Payable	147,500	0
Long-Term Debt – Current Portion	80,000	80,000
Accounts Payable	514,504	559,676
Accounts Payable to Affiliated Companies	164,953	108,907
Obligations to Third Party Suppliers	156,717	142,628
Renewable Portfolio Standards Compliance Obligations	157,580	120,239
Regulatory Liabilities	375,047	373,221
Other Current Liabilities	80,908	83,925
Total Current Liabilities	1,677,209	1,468,596
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	1,758,232	1,700,875
Regulatory Liabilities	1,557,614	1,548,081
Other Long-Term Liabilities	292,953	289,313
Total Deferred Credits and Other Liabilities	3,608,799	3,538,269
Long-Term Debt	4,346,024	4,345,085
Preferred Stock Not Subject to Mandatory Redemption	43,000	43,000
Common Shareholders' Equity:
Common Shares	0	0
Capital Surplus, Paid In	2,810,242	2,778,942
Retained Earnings	2,727,367	2,921,444
Accumulated Other Comprehensive Income	268	284
Common Shareholders' Equity	5,537,877	5,700,670
Commitments and Contingencies
Total Liabilities and Capitalization	$ 15,212,909	$ 15,095,620

XML

NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Allowance for uncollectible accounts	$ 535,114	$ 486,297
NSTAR Electric
Allowance for uncollectible accounts	$ 94,556	$ 94,958

XML

NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues	$ 3,795,643	$ 3,471,310
Operating Expenses:
Purchased Power and Transmission	1,903,246	1,389,696
Operations and Maintenance	454,562	472,433
Depreciation	312,955	289,330
Energy Efficiency Programs	222,952	199,484
Taxes Other Than Income Taxes	228,414	220,364
Total Operating Expenses	3,046,070	2,808,255
Operating Income/(Loss)	749,573	663,055
Interest Expense	194,543	153,245
Other Income, Net	88,981	71,561
Income Before Income Tax Expense	644,011	581,371
Income Tax Expense	150,972	136,045
Net Income	493,039	445,326
NSTAR Electric Company
Operating Revenues	956,283	863,176
Operating Expenses:
Purchased Power and Transmission	360,925	313,748
Operations and Maintenance	166,083	164,862
Depreciation	90,430	89,033
Amortization of Regulatory (Liabilities)/Assets, Net	22,785	29,345
Energy Efficiency Programs	86,217	80,232
Taxes Other Than Income Taxes	53,510	59,774
Total Operating Expenses	779,950	736,994
Operating Income/(Loss)	176,333	126,182
Interest Expense	44,865	38,222
Other Income, Net	39,873	29,231
Income Before Income Tax Expense	171,341	117,191
Income Tax Expense	37,528	24,452
Net Income	$ 133,813	$ 92,739

XML

NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net Income	$ 493,039	$ 445,326
Other Comprehensive Income, Net of Tax:
Changes in Funded Status of SERP Benefit Plan	1,971	1,516
Qualified Cash Flow Hedging Instruments	5	5
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,254	(817)
Other Comprehensive Income (Loss), Net of Tax	3,230	704
Comprehensive Income Attributable to Common Shareholders	494,389	444,150
NSTAR Electric Company
Net Income	133,813	92,739
Other Comprehensive Income, Net of Tax:
Changes in Funded Status of SERP Benefit Plan	(33)	(44)
Qualified Cash Flow Hedging Instruments	5	5
Changes in Unrealized Gains/(Losses) on Marketable Securities	12	(8)
Other Comprehensive Income (Loss), Net of Tax	(16)	(47)
Comprehensive Income Attributable to Common Shareholders	$ 133,797	$ 92,692

XML

NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY - USD ($) $ in Thousands	Total	Common Stock	Capital Surplus, Paid In	Retained Earnings	Accumulated Other Comprehensive Loss	NSTAR Electric	NSTAR Electric Common Stock	NSTAR Electric Capital Surplus, Paid In	NSTAR Electric Retained Earnings	NSTAR Electric Accumulated Other Comprehensive Loss
Balance (in shares) at Dec. 31, 2021		344,403,196					200
Balance at Dec. 31, 2021	$ 14,599,844	$ 1,789,092	$ 8,098,514	$ 5,005,391	$ (42,275)	$ 4,973,019	$ 0	$ 2,253,942	$ 2,718,576	$ 501
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	445,326			445,326		92,739			92,739
Dividends on Preferred Stock	(1,880)			(1,880)		(490)			(490)
Dividends on Common Stock	(219,768)			(219,768)		(71,900)			(71,900)
Other Comprehensive Income (Loss)	704				704	(47)				(47)
Balance (in shares) at Mar. 31, 2022		344,850,272					200
Balance at Mar. 31, 2022	$ 14,836,690	$ 1,789,092	8,102,618	5,229,069	(41,571)	4,993,321	$ 0	2,253,942	2,738,925	454
Balance (in shares) at Dec. 31, 2022	348,443,855	348,443,855					200
Balance at Dec. 31, 2022	$ 15,473,158	$ 1,799,920	8,401,731	5,527,153	(39,421)	5,700,670	$ 0	2,778,942	2,921,444	284
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	493,039			493,039		133,813			133,813
Dividends on Preferred Stock	(1,880)			(1,880)		(490)			(490)
Dividends on Common Stock	(235,354)			(235,354)		(327,400)			(327,400)
Capital Contributions from Eversource Parent						31,300		31,300
Other Comprehensive Income (Loss)	$ 3,230				3,230	(16)				(16)
Balance (in shares) at Mar. 31, 2023	348,808,082	348,808,082					200
Balance at Mar. 31, 2023	$ 15,749,371	$ 1,799,920	$ 8,412,085	$ 5,782,958	$ (36,191)	$ 5,537,877	$ 0	$ 2,810,242	$ 2,727,367	$ 268

XML

NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net Income	$ 493,039	$ 445,326
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	312,955	289,330
Deferred Income Taxes	149,197	67,557
Uncollectible Expense	22,821	17,135
Pension, SERP and PBOP Income, Net	(24,563)	(40,642)
Pension Contributions	(1,100)	(26,100)
Regulatory Under Recoveries, Net	(158,964)	(107,767)
Cost of Removal Expenditures	(70,514)	(61,660)
Other	(54,486)	(21,409)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(225,609)	(291,723)
Taxes Receivable/Accrued, Net	284	56,519
Accounts Payable	(258,476)	(68,909)
Other Current Assets and Liabilities, Net	(39,368)	(64,253)
Net Cash Flows (Used In)/Provided by Operating Activities	69,157	371,940
Investing Activities:
Investments in Property, Plant and Equipment	(977,144)	(764,594)
Other Investing Activities	5,640	5,976
Net Cash Flows Used in Investing Activities	(1,051,550)	(858,247)
Financing Activities:
Cash Dividends on Common Shares	(229,405)	(213,890)
Cash Dividends on Preferred Stock	(1,880)	(1,880)
(Decrease)/Increase in Notes Payable to Eversource Parent	(246,700)	163,350
Other Financing Activities	(27,002)	(26,087)
Net Cash Flows (Used in)/Provided by Financing Activities	623,408	429,888
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(358,985)	(56,419)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	521,752	221,008
Cash and Restricted Cash - End of Period	162,767	164,589
NSTAR Electric
Operating Activities:
Net Income	133,813	92,739
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	90,430	89,033
Deferred Income Taxes	44,403	26,857
Uncollectible Expense	4,697	4,662
Pension, SERP and PBOP Income, Net	(9,886)	(13,742)
Pension Contributions	0	(5,000)
Regulatory Under Recoveries, Net	(58,000)	(10,813)
Amortization of Regulatory (Liabilities)/Assets, Net	22,785	29,345
Cost of Removal Expenditures	(12,893)	(12,852)
Other	(9,921)	(5,531)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(90,684)	2,051
Taxes Receivable/Accrued, Net	11,977	45,299
Accounts Payable	20,249	(55,743)
Other Current Assets and Liabilities, Net	(6,185)	3,559
Net Cash Flows (Used In)/Provided by Operating Activities	140,785	189,864
Investing Activities:
Investments in Property, Plant and Equipment	(318,673)	(234,120)
Other Investing Activities	35	96
Net Cash Flows Used in Investing Activities	(318,638)	(234,024)
Financing Activities:
Cash Dividends on Common Shares	(327,400)	(71,900)
Cash Dividends on Preferred Stock	(490)	(490)
Capital Contributions from Eversource Parent	31,300	0
(Decrease)/Increase in Notes Payable to Eversource Parent	0	4,000
Increase in Notes Payable	147,500	112,500
Other Financing Activities	5	15
Net Cash Flows (Used in)/Provided by Financing Activities	(149,085)	44,125
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(326,938)	(35)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	345,293	18,179
Cash and Restricted Cash - End of Period	$ 18,355	$ 18,144

XML

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Current Assets:
Cash	$ 35,975	$ 47,597
Receivables, Net (net of allowance for uncollectible accounts)	1,660,076	1,517,138
Unbilled Revenues	216,715	238,968
Materials, Supplies and REC Inventory	423,343	374,395
Regulatory Assets	1,332,028	1,335,491
Prepayments and Other Current Assets	468,292	382,603
Total Current Assets	4,136,429	4,223,198
Property, Plant and Equipment, Net	36,744,855	36,112,820
Deferred Debits and Other Assets:
Total Long-Term Regulatory Assets	4,407,875	4,242,794
Prepaid Pension and PBOP	1,097,814	1,045,524
Other Long-Term Assets	560,632	541,344
Total Deferred Debits and Other Assets	13,223,883	12,894,882
Total Assets	54,105,167	53,230,900
Current Liabilities:
Long-Term Debt – Current Portion	1,615,461	1,320,129
Rate Reduction Bonds – Current Portion	43,210	43,210
Accounts Payable	1,821,911	2,113,905
Regulatory Liabilities	650,538	890,786
Other Current Liabilities	1,078,421	989,053
Total Current Liabilities	6,405,041	6,799,283
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	5,239,443	5,067,902
Regulatory Liabilities	3,974,374	3,930,305
Other Long-Term Liabilities	884,717	888,081
Total Deferred Credits and Other Liabilities	10,843,710	10,668,403
Long-Term Debt	20,562,588	19,723,994
Rate Reduction Bonds	388,887	410,492
Common Shareholders' Equity:
Capital Surplus, Paid In	8,412,085	8,401,731
Retained Earnings	5,782,958	5,527,153
Accumulated Other Comprehensive Loss	(36,191)	(39,421)
Common Shareholders' Equity	15,749,371	15,473,158
Commitments and Contingencies
Total Liabilities and Capitalization	54,105,167	53,230,900
PSNH
Current Assets:
Cash	88	136
Receivables, Net (net of allowance for uncollectible accounts)	167,960	173,337
Accounts Receivable from Affiliated Companies	25,270	8,193
Unbilled Revenues	67,266	72,713
Taxes Receivable	48,173	27,978
Materials, Supplies and REC Inventory	43,492	34,521
Regulatory Assets	140,912	102,240
Special Deposits	19,469	33,140
Prepayments and Other Current Assets	6,869	13,297
Total Current Assets	519,499	465,555
Property, Plant and Equipment, Net	4,147,985	4,060,224
Deferred Debits and Other Assets:
Total Long-Term Regulatory Assets	697,568	593,974
Prepaid Pension and PBOP	70,892	66,384
Other Long-Term Assets	15,183	16,517
Total Deferred Debits and Other Assets	783,643	676,875
Total Assets	5,451,127	5,202,654
Current Liabilities:
Notes Payable to Eversource Parent	121,100	173,300
Long-Term Debt – Current Portion	325,000	29,668
Rate Reduction Bonds – Current Portion	43,210	43,210
Accounts Payable	301,547	291,556
Accounts Payable to Affiliated Companies	51,985	36,231
Regulatory Liabilities	86,569	161,963
Other Current Liabilities	62,784	59,616
Total Current Liabilities	992,195	795,544
Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	625,374	562,802
Regulatory Liabilities	390,290	391,628
Other Long-Term Liabilities	37,418	37,087
Total Deferred Credits and Other Liabilities	1,053,082	991,517
Long-Term Debt	1,134,407	1,134,914
Rate Reduction Bonds	388,887	410,492
Common Shareholders' Equity:
Common Shares	0	0
Capital Surplus, Paid In	1,298,134	1,298,134
Retained Earnings	584,422	572,126
Accumulated Other Comprehensive Loss	0	(73)
Common Shareholders' Equity	1,882,556	1,870,187
Commitments and Contingencies
Total Liabilities and Capitalization	$ 5,451,127	$ 5,202,654

XML

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Allowance for uncollectible accounts	$ 535,114	$ 486,297
PSNH
Allowance for uncollectible accounts	$ 33,505	$ 29,236

XML

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Revenues	$ 3,795,643	$ 3,471,310
Operating Expenses:
Purchased Power and Transmission	1,903,246	1,389,696
Operations and Maintenance	454,562	472,433
Depreciation	312,955	289,330
Energy Efficiency Programs	222,952	199,484
Taxes Other Than Income Taxes	228,414	220,364
Total Operating Expenses	3,046,070	2,808,255
Operating Income/(Loss)	749,573	663,055
Interest Expense	194,543	153,245
Other Income, Net	88,981	71,561
Income Before Income Tax Expense	644,011	581,371
Income Tax Expense	150,972	136,045
Net Income	493,039	445,326
PSNH
Operating Revenues	420,155	339,427
Operating Expenses:
Purchased Power and Transmission	226,685	125,844
Operations and Maintenance	67,796	59,573
Depreciation	34,088	31,253
Amortization of Regulatory (Liabilities)/Assets, Net	(5,317)	26,834
Energy Efficiency Programs	10,226	8,718
Taxes Other Than Income Taxes	22,105	22,785
Total Operating Expenses	355,583	275,007
Operating Income/(Loss)	64,572	64,420
Interest Expense	17,542	13,645
Other Income, Net	5,717	7,509
Income Before Income Tax Expense	52,747	58,284
Income Tax Expense	12,451	12,698
Net Income	$ 40,296	$ 45,586

XML

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Net Income	$ 493,039	$ 445,326
Other Comprehensive Income/(Loss), Net of Tax:
Changes in Unrealized Gains/(Losses) on Marketable Securities	1,254	(817)
Other Comprehensive Income (Loss), Net of Tax	3,230	704
Comprehensive Income Attributable to Common Shareholders	494,389	444,150
PSNH
Net Income	40,296	45,586
Other Comprehensive Income/(Loss), Net of Tax:
Changes in Unrealized Gains/(Losses) on Marketable Securities	73	(48)
Other Comprehensive Income (Loss), Net of Tax	73	(48)
Comprehensive Income Attributable to Common Shareholders	$ 40,369	$ 45,538

XML

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY - USD ($) $ in Thousands	Total	Common Stock	Capital Surplus, Paid In	Retained Earnings	Accumulated Other Comprehensive Loss	PSNH	PSNH Common Stock	PSNH Capital Surplus, Paid In	PSNH Retained Earnings	PSNH Accumulated Other Comprehensive Loss
Balance (in shares) at Dec. 31, 2021		344,403,196					301
Balance at Dec. 31, 2021	$ 14,599,844	$ 1,789,092	$ 8,098,514	$ 5,005,391	$ (42,275)	$ 1,592,713	$ 0	$ 1,088,134	$ 504,556	$ 23
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	445,326			445,326		45,586			45,586
Dividends on Common Stock	(219,768)			(219,768)		(26,000)			(26,000)
Other Comprehensive Income (Loss)	704				704	(48)				(48)
Balance (in shares) at Mar. 31, 2022		344,850,272					301
Balance at Mar. 31, 2022	$ 14,836,690	$ 1,789,092	8,102,618	5,229,069	(41,571)	1,612,251	$ 0	1,088,134	524,142	(25)
Balance (in shares) at Dec. 31, 2022	348,443,855	348,443,855					301
Balance at Dec. 31, 2022	$ 15,473,158	$ 1,799,920	8,401,731	5,527,153	(39,421)	1,870,187	$ 0	1,298,134	572,126	(73)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	493,039			493,039		40,296			40,296
Dividends on Common Stock	(235,354)			(235,354)		(28,000)			(28,000)
Other Comprehensive Income (Loss)	$ 3,230				3,230	73				73
Balance (in shares) at Mar. 31, 2023	348,808,082	348,808,082					301
Balance at Mar. 31, 2023	$ 15,749,371	$ 1,799,920	$ 8,412,085	$ 5,782,958	$ (36,191)	$ 1,882,556	$ 0	$ 1,298,134	$ 584,422	$ 0

XML

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Operating Activities:
Net Income	$ 493,039	$ 445,326
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	312,955	289,330
Deferred Income Taxes	149,197	67,557
Uncollectible Expense	22,821	17,135
Pension, SERP and PBOP Income, Net	(24,563)	(40,642)
Regulatory Over/(Underrecoveries), Net	(158,964)	(107,767)
Cost of Removal Expenditures	(70,514)	(61,660)
Other	(54,486)	(21,409)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(225,609)	(291,723)
Taxes Receivable/Accrued, Net	284	56,519
Accounts Payable	(258,476)	(68,909)
Other Current Assets and Liabilities, Net	(39,368)	(64,253)
Net Cash Flows (Used In)/Provided by Operating Activities	69,157	371,940
Investing Activities:
Investments in Property, Plant and Equipment	(977,144)	(764,594)
Other Investing Activities	5,640	5,976
Net Cash Flows Used in Investing Activities	(1,051,550)	(858,247)
Financing Activities:
Cash Dividends on Common Shares	(229,405)	(213,890)
Issuance of Long-Term Debt	1,550,000	1,300,000
Repayment of Rate Reduction Bonds	(21,605)	(21,605)
(Decrease)/Increase in Notes Payable to Eversource Parent	(246,700)	163,350
Other Financing Activities	(27,002)	(26,087)
Net Cash Flows (Used in)/Provided by Financing Activities	623,408	429,888
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(358,985)	(56,419)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	521,752	221,008
Cash and Restricted Cash - End of Period	162,767	164,589
PSNH
Operating Activities:
Net Income	40,296	45,586
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	34,088	31,253
Deferred Income Taxes	62,924	7,480
Uncollectible Expense	5,060	2,496
Pension, SERP and PBOP Income, Net	(2,552)	(3,997)
Regulatory Over/(Underrecoveries), Net	(175,865)	(32,186)
Amortization of Regulatory (Liabilities)/Assets, Net	(5,317)	26,834
Cost of Removal Expenditures	(4,508)	(7,131)
Other	1,711	(4,631)
Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	(21,230)	(25,972)
Taxes Receivable/Accrued, Net	(20,195)	8,067
Accounts Payable	10,265	9,389
Other Current Assets and Liabilities, Net	2,462	895
Net Cash Flows (Used In)/Provided by Operating Activities	(72,861)	58,083
Investing Activities:
Investments in Property, Plant and Equipment	(133,890)	(107,916)
Other Investing Activities	216	593
Net Cash Flows Used in Investing Activities	(133,674)	(107,323)
Financing Activities:
Cash Dividends on Common Shares	(28,000)	(26,000)
Issuance of Long-Term Debt	300,000	0
Repayment of Rate Reduction Bonds	(21,605)	(21,605)
(Decrease)/Increase in Notes Payable to Eversource Parent	(52,200)	85,800
Other Financing Activities	(5,460)	(23)
Net Cash Flows (Used in)/Provided by Financing Activities	192,735	38,172
Net Decrease in Cash, Cash Equivalents and Restricted Cash	(13,800)	(11,068)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period	36,812	35,126
Cash and Restricted Cash - End of Period	$ 23,012	$ 24,058

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

3 Months Ended

Mar. 31, 2023

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

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, NSTAR Gas and EGMA (natural gas utilities), and Aquarion (water utilities). Eversource provides energy delivery and/or water service to approximately 4.4 million electric, natural gas and water customers through twelve regulated utilities in Connecticut, Massachusetts and New Hampshire.

The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries.  Intercompany transactions have been eliminated in consolidation.  The accompanying unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P 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 2022 Form 10-K, which was filed with the SEC on February 15, 2023. 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 March 31, 2023 and December 31, 2022, and the results of operations, comprehensive income, common shareholders' equity and cash flows for the three months ended March 31, 2023 and 2022. The results of operations, comprehensive income and cash flows for the three months ended March 31, 2023 and 2022 are not necessarily indicative of the results expected for a full year.  

CYAPC and YAEC are inactive regional nuclear power companies engaged in the long-term storage of their spent nuclear fuel. Eversource consolidates the operations of 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.

Certain reclassifications of prior period data were made in the accompanying financial statements to conform to the current period presentation.

B.    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). The current expected credit loss (CECL) model is applied to receivables for purposes of calculating the allowance for uncollectible accounts. This 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 an aging-based quantitative assessment that applies an estimated uncollectible percentage to each receivable aging category.  Factors in determining credit loss include historical collection, write-off experience, analysis of delinquency statistics, and management's assessment of collectability from customers, including current economic conditions, customer payment trends, the impact on customer bills because of energy usage trends and changes in rates, flexible payment plans and financial hardship arrearage management programs being offered to customers, reasonable forecasts, and expectations of future collectability and collection efforts. Management continuously assesses the collectability of receivables and adjusts estimates based on actual experience and future expectations based on economic conditions, 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 allowance for uncollectible accounts when the customer accounts are no longer in service and these balances are deemed to be uncollectible. Management concluded that the reserve balance as of March 31, 2023 adequately reflected the collection risk and net realizable value for its receivables.

As of both March 31, 2023 and December 31, 2022, the total amount incurred as a result of COVID-19 included in the allowance for uncollectible accounts was $50.9 million at Eversource, $16.0 million at CL&P, and $4.1 million at NSTAR Electric. At our Connecticut and Massachusetts utilities, the 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 future rates. No COVID-19 related uncollectible amounts were deferred at PSNH as a result of a July 2021 NHPUC order. Based on the status of our COVID-19 regulatory dockets, policies and practices in the jurisdictions in which we operate, we believe the state regulatory commissions in Connecticut and Massachusetts will allow us to recover our incremental uncollectible customer receivable costs associated with COVID-19.

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, NSTAR Gas and EGMA 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. Management uses a higher credit risk profile for this pool of trade receivables as compared to non-hardship receivables. The allowance for uncollectible hardship accounts is included in the total uncollectible allowance balance.

The total allowance for uncollectible accounts is included in Receivables, Net on the balance sheets. The activity in the allowance for uncollectible accounts by portfolio segment as of March 31st is as follows:

	Eversource						CL&P						NSTAR Electric						PSNH
(Millions of Dollars)	Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Total Allowance
Three Months Ended 2023
Beginning Balance	$	284.4	$	201.9	$	486.3	$	188.9	$	36.4	$	225.3	$	43.7	$	51.3	$	95.0	$	29.2
Uncollectible Expense	—		22.8		22.8		—		3.9		3.9		—		4.7		4.7		5.1
Uncollectible Costs Deferred (1)	43.7		14.3		58.0		34.3		2.7		37.0		(1.3)		5.4		4.1		1.2
Write-Offs	(9.7)		(26.3)		(36.0)		(7.3)		(7.0)		(14.3)		(0.4)		(10.3)		(10.7)		(2.2)
Recoveries Collected	0.3		3.7		4.0		0.3		1.2		1.5		—		1.5		1.5		0.2
Ending Balance	$	318.7	$	216.4	$	535.1	$	216.2	$	37.2	$	253.4	$	42.0	$	52.6	$	94.6	$	33.5

Three Months Ended 2022
Beginning Balance	$	226.1	$	191.3	$	417.4	$	144.6	$	36.7	$	181.3	$	43.3	$	53.7	$	97.0	$	24.3
Uncollectible Expense	—		17.1		17.1		—		3.8		3.8		—		4.7		4.7		2.5
Uncollectible Costs Deferred (1)	0.9		14.8		15.7		(4.0)		(2.1)		(6.1)		(3.3)		5.4		2.1		1.0
Write-Offs	(2.3)		(22.0)		(24.3)		(1.1)		(0.5)		(1.6)		(0.3)		(10.6)		(10.9)		(1.8)
Recoveries Collected	0.8		5.5		6.3		0.6		2.5		3.1		—		1.9		1.9		0.2
Ending Balance	$	225.5	$	206.7	$	432.2	$	140.1	$	40.4	$	180.5	$	39.7	$	55.1	$	94.8	$	26.2

(1) These expected credit losses are deferred as regulatory costs on the balance sheets, as these amounts are ultimately recovered in rates. Amounts include uncollectible costs for hardship accounts and other customer receivables, including uncollectible amounts related to uncollectible energy supply costs and COVID-19. The increase in the allowance for uncollectible hardship accounts in 2023 at Eversource and CL&P primarily relates to increased customer enrollment in disconnection prevention programs in Connecticut.

C.    Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" (normal) and to 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, equity method investments, AROs, and in the valuation of business combinations and asset acquisitions. The fair value measurement guidance was also applied in estimating the 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. The 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 10, "Fair Value of Financial Instruments," to the financial statements.

D.    Other Income, Net

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

	For the Three Months Ended
	March 31, 2023								March 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Pension, SERP and PBOP Non-Service    Income Components, Net of Deferred Portion	$	34.8	$	9.5	$	14.7	$	4.2	$	54.3	$	15.9	$	21.0	$	6.6
AFUDC Equity	15.5		4.1		9.5		0.7		9.9		2.8		4.9		0.4
Equity in Earnings of Unconsolidated Affiliates	3.8		—		0.1		—		0.4		—		—		—
Investment (Loss)/Income	(1.7)		(0.6)		(0.5)		(0.1)		(0.2)		(0.4)		(0.3)		0.2
Interest Income	23.1		1.9		16.0		0.9		6.7		1.3		3.5		0.3
Other	13.5		—		0.1		—		0.5		—		0.1		—
Total Other Income, Net	$	89.0	$	14.9	$	39.9	$	5.7	$	71.6	$	19.6	$	29.2	$	7.5

E.    Investments in Unconsolidated Affiliates

Investments in entities that are not consolidated are included in long-term assets on the balance sheets and earnings impacts from these equity investments are included in Other Income, Net on the statements of income.  Eversource's investments included the following:

			Investment Balance
(Millions of Dollars)	Ownership Interest		As of March 31, 2023		As of December 31, 2022
Offshore Wind Business - North East Offshore	50	%	$	2,159.2	$	1,947.1
Natural Gas Pipeline - Algonquin Gas Transmission, LLC	15	%	117.5		118.8
Renewable Energy Investment Fund	90	%	—		84.1
Other	various		26.2		26.1
Total Investments in Unconsolidated Affiliates			$	2,302.9	$	2,176.1

Offshore Wind Business: Eversource’s offshore wind business includes a 50 percent ownership interest in North East Offshore, which holds PPAs and contracts for the Revolution Wind, South Fork Wind and Sunrise Wind projects, as well as an undeveloped offshore lease area. The offshore wind investment includes capital expenditures for the three offshore wind projects, as well as capitalized costs related to future development, acquisition costs of offshore lease areas, and capitalized interest.

On May 4, 2022, Eversource announced that it had initiated a strategic review of its offshore wind investment portfolio. As part of that review, Eversource is exploring strategic alternatives that could result in a potential sale of all, or part, of its 50 percent interest in its offshore wind partnership with Ørsted. Eversource continues to work with interested parties through this ongoing process and expects to complete this review in the second quarter of 2023. Eversource’s strategic review of its offshore wind investment does not impact the presentation of the March 31, 2023 financial statements.

Equity method investments are assessed for impairment when conditions exist that indicate that the fair value of the investment is less than book value. Eversource continually monitors and evaluates its equity method investments to determine if there are indicators of an other-than-temporary impairment. Eversource believes that the fair market value of its offshore wind investment is greater than the carrying value based upon management’s expectation for future cash flows arising from the sale of all, or part, of its investment. There are uncertainties in a sale process, and there could be changes in market conditions that would impact Eversource’s ability to sell this investment or the value it would receive for these assets. In the event that the strategic review does not result in the sale of the offshore wind business or that a sale of the offshore wind business is significantly delayed or at a lower than expected value from these changes in market conditions driven by unfavorable developments, such as scheduling or permitting delays, increases in actual costs and cost estimates, changes to tax laws impacting the project’s ability to monetize tax attributes, higher interest rates, and increases in the discount rate, it could result in Eversource having to evaluate whether or not its investment is impaired. Any resulting impairment charge could have a material adverse effect on Eversource’s financial position and results of operations.

Liquidation of Renewable Energy Investment Fund: On March 21, 2023, Eversource’s equity method investment in a renewable energy investment fund was liquidated by the fund’s general partner in accordance with the partnership agreement. Proceeds received from the liquidation were $123.4 million and are included in Investments in Unconsolidated Affiliates within investing activities on the statement of cash flows. Additional amounts in escrow as of March 31, 2023 resulting from the liquidation were received in the second quarter of 2023. A portion of the proceeds were used to make a charitable contribution to the Eversource Energy Foundation (a related party) of $20.0 million in the first quarter of 2023. The liquidation benefit and charitable contribution are included in Other Income, Net on the statement of income.

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
(Millions of Dollars)	March 31, 2023		March 31, 2022
Eversource	$	55.0	$	48.6
CL&P	43.1		37.8

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

G.    Supplemental Cash Flow Information

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

(Millions of Dollars)	As of March 31, 2023		As of March 31, 2022
Eversource	$	400.8	$	385.6
CL&P	101.9		102.1
NSTAR Electric	117.4		85.8
PSNH	54.6		49.5

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 March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Cash and Cash Equivalents as reported on the Balance Sheets	$	36.0	$	9.3	$	0.6	$	0.1	$	374.6	$	11.3	$	327.7	$	0.1
Restricted cash included in:
Special Deposits	89.0		8.9		17.8		19.5		102.2		8.8		17.5		33.1
Marketable Securities	17.9		0.2		—		0.2		25.4		0.2		0.1		0.4
Other Long-Term Assets	19.9		—		—		3.2		19.6		—		—		3.2
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows	$	162.8	$	18.4	$	18.4	$	23.0	$	521.8	$	20.3	$	345.3	$	36.8

Special Deposits represent cash collections related to the PSNH RRB customer charges that are held in trust, required ISO-NE cash deposits, cash held in escrow accounts, 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 obligations.

Restricted cash includes an Energy Relief Fund for energy efficiency and clean energy measures in the Merrimack Valley and an additional energy efficiency program established under the terms of the EGMA 2020 settlement agreement. This restricted cash included $20.0 million recorded as short-term in Special Deposits as of both March 31, 2023 and December 31, 2022, and $16.7 million and $15.9 million recorded in Other Long-Term Assets on the balance sheets as of March 31, 2023 and December 31, 2022, respectively.

XML

REGULATORY ACCOUNTING

3 Months Ended

Mar. 31, 2023

Regulated Operations [Abstract]

REGULATORY ACCOUNTING

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, 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 and the regulatory assets that have been recorded.  If management were to determine that it could no longer apply the accounting guidance applicable to rate-regulated enterprises, or if management could not conclude it is probable that costs would be recovered from customers in future rates, the applicable 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 March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Storm Costs, Net	$	1,658.7	$	889.2	$	564.9	$	204.6	$	1,379.1	$	799.3	$	484.4	$	95.4
Regulatory Tracking Mechanisms	1,028.7		228.2		432.4		122.8		1,075.3		216.8		391.5		73.7
Benefit Costs	910.3		155.6		294.4		56.1		921.7		156.7		299.5		56.6
Income Taxes, Net	856.1		492.9		118.1		13.1		853.3		491.1		115.6		16.0
Securitized Stranded Costs	424.9		—		—		424.9		435.7		—		—		435.7
Goodwill-related	276.7		—		237.6		—		281.0		—		241.2		—
Derivative Liabilities	168.8		168.8		—		—		181.8		181.8		—		—
Asset Retirement Obligations	129.2		36.5		68.0		4.5		127.9		35.9		68.2		4.4
Other Regulatory Assets	286.5		25.3		107.9		12.5		322.5		26.2		114.0		14.4
Total Regulatory Assets	5,739.9		1,996.5		1,823.3		838.5		5,578.3		1,907.8		1,714.4		696.2
Less:  Current Portion	1,332.0		356.5		559.8		140.9		1,335.5		314.1		492.8		102.2
Total Long-Term Regulatory Assets	$	4,407.9	$	1,640.0	$	1,263.5	$	697.6	$	4,242.8	$	1,593.7	$	1,221.6	$	594.0

Regulatory Costs in Long-Term Assets:  Eversource's regulated companies had $223.6 million (including $146.5 million for CL&P, $19.7 million for NSTAR Electric and $1.1 million for PSNH) and $210.8 million (including $135.9 million for CL&P, $19.8 million for NSTAR Electric and $1.0 million for PSNH) of additional regulatory costs as of March 31, 2023 and December 31, 2022, 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 both March 31, 2023 and December 31, 2022, these regulatory costs included incremental COVID-19 related non-tracked uncollectible expense deferred of $29.8 million at Eversource, $11.8 million at CL&P, and $2.2 million at NSTAR Electric.

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

	As of March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
EDIT due to Tax Cuts and Jobs Act of 2017	$	2,601.8	$	980.0	$	933.9	$	346.1	$	2,619.3	$	983.6	$	944.3	$	348.6
Cost of Removal	705.4		144.2		412.9		20.2		670.6		130.8		405.3		14.7
Regulatory Tracking Mechanisms	653.6		145.0		341.6		73.2		890.8		361.0		336.1		155.0
Deferred Portion of Non-Service Income    Components of Pension, SERP and PBOP	291.4		38.3		148.5		30.8		270.9		34.5		139.7		28.8
AFUDC - Transmission	103.8		49.8		54.0		—		98.2		48.2		50.0		—
Benefit Costs	49.2		0.6		27.1		—		55.4		0.7		31.4		—
Other Regulatory Liabilities	219.7		44.0		14.6		6.6		215.9		40.6		14.5		6.5
Total Regulatory Liabilities	4,624.9		1,401.9		1,932.6		476.9		4,821.1		1,599.4		1,921.3		553.6
Less:  Current Portion	650.5		124.6		375.0		86.6		890.8		336.0		373.2		162.0
Total Long-Term Regulatory Liabilities	$	3,974.4	$	1,277.3	$	1,557.6	$	390.3	$	3,930.3	$	1,263.4	$	1,548.1	$	391.6

XML

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

3 Months Ended

Mar. 31, 2023

Property, Plant and Equipment [Abstract]

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION

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

Eversource	As of March 31, 2023		As of December 31, 2022
(Millions of Dollars)
Distribution - Electric	$	18,618.6	$	18,326.2
Distribution - Natural Gas	7,562.8		7,443.8
Transmission - Electric	13,884.0		13,709.3
Distribution - Water	2,122.5		2,112.6
Solar	200.8		200.8
Utility	42,388.7		41,792.7
Other (1)	1,791.7		1,738.1
Property, Plant and Equipment, Gross	44,180.4		43,530.8
Less:  Accumulated Depreciation
Utility	(9,317.7)		(9,167.4)
Other	(744.7)		(706.1)
Total Accumulated Depreciation	(10,062.4)		(9,873.5)
Property, Plant and Equipment, Net	34,118.0		33,657.3
Construction Work in Progress	2,626.9		2,455.5
Total Property, Plant and Equipment, Net	$	36,744.9	$	36,112.8

	As of March 31, 2023						As of December 31, 2022
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Distribution - Electric	$	7,510.8	$	8,516.7	$	2,631.4	$	7,370.1	$	8,410.0	$	2,586.4
Transmission - Electric	6,235.2		5,382.8		2,267.6		6,165.1		5,333.8		2,212.0
Solar	—		200.8		—		—		200.8		—
Property, Plant and Equipment, Gross	13,746.0		14,100.3		4,899.0		13,535.2		13,944.6		4,798.4
Less:  Accumulated Depreciation	(2,610.4)		(3,429.3)		(940.0)		(2,567.1)		(3,381.2)		(912.3)
Property, Plant and Equipment, Net	11,135.6		10,671.0		3,959.0		10,968.1		10,563.4		3,886.1
Construction Work in Progress	494.7		1,148.0		189.0		498.9		1,063.6		174.1
Total Property, Plant and Equipment, Net	$	11,630.3	$	11,819.0	$	4,148.0	$	11,467.0	$	11,627.0	$	4,060.2

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

XML

DERIVATIVE INSTRUMENTS

3 Months Ended

Mar. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

DERIVATIVE INSTRUMENTS

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 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 March 31, 2023						As of December 31, 2022
CL&P (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
Current Derivative Assets	Level 3	$	17.0	$	(0.5)	$	16.5	$	16.3	$	(0.5)	$	15.8
Long-Term Derivative Assets	Level 3	24.9		(0.8)		24.1		28.8		(0.9)		27.9
Current Derivative Liabilities	Level 3	(85.1)		—		(85.1)		(81.6)		—		(81.6)
Long-Term Derivative Liabilities	Level 3	(124.3)		—		(124.3)		(143.9)		—		(143.9)

    

(1)    Amounts represent derivative assets and liabilities that Eversource elected to record net on the balance sheets.  These amounts are subject to master netting agreements or similar agreements for which the right of offset exists.

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 March 31, 2023 and December 31, 2022 were 674 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. 

Fair Value Measurements of Derivative Instruments

The fair value of derivative contracts classified as Level 3 utilizes both significant observable and unobservable inputs.  The fair value is modeled using income techniques, such as discounted cash flow valuations adjusted for assumptions related to exit price.  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.  Significant observable inputs for valuations of these contracts include energy-related product prices in future years for which quoted prices in an active market exist. 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.  Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy-related products, and accounting requirements.

The following is a summary of the significant unobservable inputs utilized in the valuations of the derivative contracts classified as Level 3:

	As of March 31, 2023								As of December 31, 2022
CL&P	Range				Average			Period Covered	Range				Average			Period Covered
Forward Reserve Prices	$	0.44	—	$0.50	$	0.47	per kW-Month	2023 - 2024	$	0.44	—	$0.50	$	0.47	per kW-Month	2023 - 2024

Exit price premiums of 2.3 percent through 6.6 percent, or a weighted average of 5.5 percent, are also Level 3 significant unobservable inputs 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.  

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 March 31,
(Millions of Dollars)	2023		2022
Derivatives, Net:
Fair Value as of Beginning of Period	$	(181.8)	$	(249.2)
Net Realized/Unrealized (Losses)/Gains Included in Regulatory Assets	(1.9)		6.2
Settlements	14.9		13.6
Fair Value as of End of Period	$	(168.8)	$	(229.4)

XML

MARKETABLE SECURITIES

3 Months Ended

Mar. 31, 2023

Investments, Debt and Equity Securities [Abstract]

MARKETABLE SECURITIES

MARKETABLE SECURITIES

Eversource holds marketable securities that are primarily used to fund certain non-qualified executive benefits.  The trusts that hold these marketable securities are not subject to regulatory oversight by state or federal agencies.  Eversource’s marketable securities also include the CYAPC and YAEC legally restricted trusts that each hold equity and available-for-sale debt securities to fund the spent nuclear fuel removal obligations of their nuclear fuel storage facilities. Equity and available-for-sale debt marketable securities are recorded at fair value, with the current portion recorded in Prepayments and Other Current Assets and the long-term portion recorded in Marketable Securities on the balance sheets.

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 March 31, 2023 and December 31, 2022 was $19.6 million and $20.0 million, respectively.  For the three months ended March 31, 2023 and 2022, there were unrealized gains of $0.8 million and unrealized losses of $4.4 million, respectively, recorded in Other Income, Net related to these equity securities.

Eversource's equity securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of $170.9 million and $170.1 million as of March 31, 2023 and December 31, 2022, 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 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:

	As of March 31, 2023								As of December 31, 2022
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
Debt Securities	$	196.5	$	0.2	$	(14.8)	$	181.9	$	201.6	$	0.1	$	(16.2)	$	185.5

Unrealized gains and losses on available-for-sale debt securities held in Eversource's non-qualified executive benefit trust are recorded in Accumulated Other Comprehensive Income, excluding amounts related to credit losses or losses on securities intended to be sold, which are recorded in Other Income, Net. There were $1.2 million of unrealized losses recorded on securities intended to be sold for the three months ended March 31, 2023 that were included in Other Income, Net. There have been no credit losses for the three months ended March 31, 2023 and 2022, and no allowance for credit losses as of March 31, 2023. Factors considered in determining whether a credit loss exists include adverse conditions specifically affecting the issuer, the payment history, ratings and rating changes of the security, and the severity of the impairment.  For 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.

Eversource's debt securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts in the amounts of $161.2 million and $163.2 million as of March 31, 2023 and December 31, 2022, respectively. Unrealized gains and losses for available-for-sale debt securities included in the CYAPC and YAEC spent nuclear fuel trusts are subject to regulatory accounting treatment and are recorded in Marketable Securities with the corresponding offset to long-term liabilities on the balance sheets, with no impact on the statements of income. Pre-tax unrealized gains and losses as of March 31, 2023 and December 31, 2022 primarily relate to the debt securities included in CYAPC's and YAEC's spent nuclear fuel trusts.

As of March 31, 2023, the contractual maturities of available-for-sale debt securities were as follows:

 

Eversource (Millions of Dollars)	Amortized Cost		Fair Value
Less than one year (1)	$	39.8	$	38.9
One to five years	42.5		41.1
Six to ten years	35.6		32.8
Greater than ten years	78.6		69.1
Total Debt Securities	$	196.5	$	181.9

(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. Amounts also include securities in Eversource’s non-qualified executive benefit trust, which are intended to be sold in 2023.

Realized Gains and Losses:  Realized gains and losses are recorded in Other Income, Net for Eversource's benefit trust and are offset in 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 March 31, 2023		As of December 31, 2022
Level 1:
Mutual Funds and Equities	$	190.5	$	190.1
Money Market Funds	17.9		25.4
Total Level 1	$	208.4	$	215.5
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury)	$	91.5	$	82.3
Corporate Debt Securities	44.2		46.1
Asset-Backed Debt Securities	8.5		8.6
Municipal Bonds	9.2		12.7
Other Fixed Income Securities	10.6		10.4
Total Level 2	$	164.0	$	160.1
Total Marketable Securities	$	372.4	$	375.6

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.

XML

SHORT-TERM AND LONG-TERM DEBT

3 Months Ended

Mar. 31, 2023

Debt Disclosure [Abstract]

SHORT-TERM AND LONG-TERM DEBT

SHORT-TERM AND LONG-TERM DEBT

Short-Term Debt - Commercial Paper Programs and Credit Agreements: Eversource parent has a $2.00 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas, EGMA and Aquarion Water Company of Connecticut are parties to a five-year $2.00 billion revolving credit facility, which terminates on October 15, 2027. This revolving credit facility serves to backstop Eversource parent's $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 October 15, 2027, and 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
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
(Millions of Dollars)
Eversource Parent Commercial Paper Program	$	1,048.0	$	1,442.2	$	952.0	$	557.8	5.22	%	4.63	%
NSTAR Electric Commercial Paper Program	147.5		—		502.5		650.0		4.77	%	—	%

There were no borrowings outstanding on the revolving credit facilities as of March 31, 2023 or December 31, 2022.

CL&P and PSNH have uncommitted line of credit agreements totaling $450 million and $300 million, respectively, which will expire on May 12, 2023. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of March 31, 2023.

Amounts outstanding under the commercial paper programs are included in Notes Payable and 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.

Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. 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 March 31, 2023, there were intercompany loans from Eversource parent to CL&P of $318.0 million and to PSNH of $121.1 million. As of December 31, 2022, there were intercompany loans from Eversource parent to PSNH of $173.3 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time.

Sources and Uses of Cash: The Company expects the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with 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.

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

(Millions of Dollars)	Interest Rate		Issuance/(Repayment)		Issue Date or Repayment Date	Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P 2023 Series A First Mortgage Bonds	5.25	%	$	500.0	January 2023	January 2053	Repaid 2013 Series A Bonds at maturity and short-term debt, and paid capital expenditures and working capital
CL&P 2013 Series A First Mortgage Bonds	2.50	%	(400.0)		January 2023	January 2023	Paid at maturity
PSNH Series W First Mortgage Bonds	5.15	%	300.0		January 2023	January 2053	Repaid short-term debt, paid capital expenditures and working capital
Eversource Parent Series Z Senior Notes	5.45	%	750.0		March 2023	March 2028	Repaid Series F Senior Notes at maturity and short-term debt
Eversource Parent Series F Senior Notes	2.80	%	(450.0)		May 2023	May 2023	Paid at maturity

XML

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

3 Months Ended

Mar. 31, 2023

Rate Reduction Bonds and Variable Interest Entity [Abstract]

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES

Rate Reduction Bonds: In May 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 are paid semi-annually, beginning on February 1, 2019. The RRBs were issued pursuant to a finance order issued by the NHPUC in January 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)
PSNH Balance Sheets:	As of March 31, 2023		As of December 31, 2022
Restricted Cash - Current Portion (included in Current Assets)	$	18.7	$	32.4
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2
Securitized Stranded Cost (included in Regulatory Assets)	424.9		435.7
Other Regulatory Liabilities (included in Regulatory Liabilities)	8.8		6.0
Accrued Interest (included in Other Current Liabilities)	2.7		6.9
Rate Reduction Bonds - Current Portion	43.2		43.2
Rate Reduction Bonds - Long-Term Portion	388.9		410.5

(Millions of Dollars) PSNH Income Statements:	For the Three Months Ended
	March 31, 2023		March 31, 2022
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	$	10.8	$	10.8
Interest Expense on RRB Principal (included in Interest Expense)	4.1		4.4

XML

PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION

3 Months Ended

Mar. 31, 2023

Postemployment Benefits [Abstract]

PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION

PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION

Eversource provides defined benefit retirement plans (Pension Plans) that cover eligible employees.  In addition to the Pension Plans, Eversource maintains non-qualified defined benefit retirement 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) 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.

The components of net periodic benefit plan expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets/(liabilities) for future recovery or refund, are shown below.  The service cost component of net periodic benefit plan 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 plan 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 intercompany allocations of net periodic benefit plan expense/(income), as these amounts are cash settled on a short-term basis.

	Pension and SERP								PBOP
	For the Three Months Ended March 31, 2023								For the Three Months Ended March 31, 2023
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Service Cost	$	11.0	$	3.0	$	2.1	$	1.1	$	1.8	$	0.3	$	0.3	$	0.2
Interest Cost	63.7		12.6		13.5		6.8		8.5		1.6		2.3		0.9
Expected Return on Plan Assets	(115.9)		(23.4)		(28.4)		(12.3)		(19.1)		(2.4)		(9.2)		(1.4)
Actuarial Loss	12.5		0.8		4.9		0.4		—		—		—		—
Prior Service Cost/(Credit)	0.3		—		0.1		—		(5.4)		0.3		(4.2)		0.1
Total Net Periodic Benefit Plan Income	$	(28.4)	$	(7.0)	$	(7.8)	$	(4.0)	$	(14.2)	$	(0.2)	$	(10.8)	$	(0.2)
Intercompany Income Allocations	N/A		$	(2.0)	$	(1.7)	$	(0.5)	N/A		$	(0.5)	$	(0.6)	$	(0.2)
	Pension and SERP								PBOP
	For the Three Months Ended March 31, 2022								For the Three Months Ended March 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Service Cost	$	17.7	$	4.5	$	3.6	$	1.8	$	2.8	$	0.5	$	0.5	$	0.2
Interest Cost	38.6		7.8		8.1		4.2		5.0		0.9		1.3		0.5
Expected Return on Plan Assets	(131.7)		(26.6)		(32.0)		(14.1)		(22.4)		(2.8)		(10.6)		(1.6)
Actuarial Loss	30.7		4.2		8.5		2.2		—		—		—		—
Prior Service Cost/(Credit)	0.4		—		0.1		—		(5.4)		0.2		(4.3)		0.1
Total Net Periodic Benefit Plan Income	$	(44.3)	$	(10.1)	$	(11.7)	$	(5.9)	$	(20.0)	$	(1.2)	$	(13.1)	$	(0.8)
Intercompany Income Allocations	N/A		$	(3.8)	$	(2.9)	$	(0.8)	N/A		$	(0.9)	$	(0.9)	$	(0.3)

XML

COMMITMENTS AND CONTINGENCIES

3 Months Ended

Mar. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

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 March 31, 2023			As of December 31, 2022
	Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)
Eversource	59	$	121.2	59	$	122.6
CL&P	13	13.6		13	13.9
NSTAR Electric	10	3.4		10	3.4
PSNH	8	6.1		8	6.1

Included in the number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured natural 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 $111.7 million and $112.6 million as of March 31, 2023 and December 31, 2022, 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.    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. Management does not anticipate a material impact to net income or cash flows as a result of these various guarantees and indemnifications. 

Guarantees issued on behalf of unconsolidated entities, including equity method offshore wind investments, for which Eversource parent is the guarantor, are recorded at fair value as a liability on the balance sheet at the inception of the guarantee. Eversource regularly reviews performance risk under these guarantee arrangements, 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. The fair value of guarantees issued on behalf of unconsolidated entities are recorded within Other Long-Term Liabilities on the balance sheet, and were $5.4 million and $4.2 million as of March 31, 2023 and December 31, 2022, respectively.

The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries and affiliates to external parties, and primarily relates to its offshore wind business:  

As of March 31, 2023
Company (Obligor)	Description	Maximum Exposure (in millions)		Expiration Dates
North East Offshore LLC	Construction-related purchase agreements with third-party contractors (1)	$	726.2	(1)
Sunrise Wind LLC	Construction-related purchase agreements with third-party contractors (2)	668.6		2025 - 2028
Revolution Wind, LLC	Construction-related purchase agreements with third-party contractors (3)	409.7		2024 - 2027
South Fork Wind, LLC	Construction-related purchase agreements with third-party contractors (4)	126.2		2023 - 2026
Eversource Investment LLC	Funding and indemnification obligations of North East Offshore LLC (5)	68.9		(5)
South Fork Wind, LLC	Power Purchase Agreement Security (6)	7.1		(6)
Sunrise Wind LLC	OREC capacity production (7)	11.0		(7)
Bay State Wind LLC	Real estate purchase	2.5		2023
South Fork Wind, LLC	Transmission interconnection	1.2		—
Eversource Investment LLC	Letters of Credit (8)	4.3		—
Various	Surety bonds (9)	37.2		2023 - 2024
Eversource Service	Lease payments for real estate	0.4		2024

(1)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, North East Offshore LLC (NEO), under which Eversource parent agreed to guarantee 50 percent of NEO’s performance of obligations under certain purchase agreements with third-party contractors, in an aggregate amount not to exceed $1.3 billion with an expiration date in 2025. Eversource parent also issued a separate guarantee to Ørsted on behalf of NEO, under which Eversource parent agreed to guarantee 50 percent of NEO’s payment obligations under certain offshore wind project construction-related agreements with Ørsted in an aggregate amount not to exceed $62.5 million and expiring upon full performance of the guaranteed obligation. Any amounts paid under this guarantee to Ørsted will count toward, but not increase, the maximum amount of the Funding Guarantee described in Note 5, below.

(2)     Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guarantee Sunrise Wind LLC's performance of certain obligations, in an aggregate amount not to exceed $838.4 million, in connection with construction-related purchase agreements. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging from March 2025 and October 2028 and (ii) full performance of the guaranteed obligations.     

(3)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, Revolution Wind, LLC, whereby Eversource parent will guarantee Revolution Wind, LLC's performance of certain obligations, in an aggregate amount not to exceed $547.1 million, in connection with construction-related purchase agreements. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging from May 2024 and November 2027 and (ii) full performance of the guaranteed obligations.

(4)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, South Fork Wind, LLC, whereby Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations in connection with construction-related purchase agreements. Under these guarantees, Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations, in a total aggregate amount not to exceed $207.7 million. Eversource parent’s obligations under these guarantees expire upon the earlier of (i) dates ranging from June 2023 and August 2026 and (ii) full performance of the guaranteed obligations.

(5)    Eversource parent issued a guarantee (Funding Guarantee) on behalf of Eversource Investment LLC (EI), its wholly-owned subsidiary that holds a 50 percent ownership interest in NEO, under which Eversource parent agreed to guarantee certain funding obligations and certain indemnification payments of EI under the operating agreement of NEO, in an amount not to exceed $910 million. The guaranteed obligations include payment of EI's funding obligations during the construction phase of NEO’s underlying offshore wind projects and indemnification obligations associated with third party credit support for its investment in NEO. Eversource parent’s obligations under the Funding Guarantee expire upon the full performance of the guaranteed obligations.

(6)    Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, South Fork Wind, LLC, whereby Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations, in an amount not to exceed $7.1 million, under a Power Purchase Agreement between the Long Island Power Authority and South Fork Wind, LLC (the Agreement). The guarantee expires upon the later of (i) the end of the Agreement term and (ii) full performance of the guaranteed obligations.

(7)    Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guarantee 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 by and between the New York State Energy Research and Development Authority (NYSERDA) and Sunrise Wind LLC. The guarantee expires upon the full performance of the guaranteed obligations.

(8)    On September 16, 2020, Eversource parent entered into a guarantee on behalf of EI, which holds Eversource's investments in offshore wind-related equity method investments, under which Eversource parent would guarantee EI's obligations under a letter of credit facility with a financial institution that EI may request in an aggregate amount of up to approximately $25 million. In January 2022, EI issued two letters of credit on behalf of South Fork Wind, LLC related to future decommissioning obligations of certain onshore transmission assets totaling $4.3 million.

(9)    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.

Second Quarter 2023 Guarantees: In the second quarter of 2023, Eversource parent issued an additional guaranty on behalf of Sunrise Wind LLC totaling $86.1 million, whereby Eversource parent will guarantee Sunrise Wind LLC’s performance of certain construction obligations.

C.     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 waste disposal contracts between the Yankee Companies and the DOE. The court previously awarded the Yankee Companies damages for Phases I, II, III and IV of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2016, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.

DOE Phase V Damages - On March 25, 2021, each of the Yankee Companies filed a fifth set of lawsuits against the DOE in the Court of Federal Claims resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2017 to 2020. The Yankee Companies filed claims seeking monetary damages totaling $120.4 million for CYAPC, YAEC and MYAPC. Pursuant to a June 2, 2022 court order, the Yankee Companies were subsequently permitted to include monetary damages relating to the year 2021 in the DOE Phase V complaint. The Yankee Companies submitted a supplemental filing to include these costs of $33.1 million on June 8, 2022. The DOE Phase V trial is now expected to begin in the fourth quarter of 2023.

D.    FERC ROE Complaints

Four separate complaints 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). 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) 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, FERC issued Opinion No. 531-A and 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).

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 both March 31, 2023 and December 31, 2022. 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 both March 31, 2023 and December 31, 2022.

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. 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 illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.

If the results of 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. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC 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. On November 19, 2020, the FERC issued Opinion No. 569-B denying rehearing of Opinion No. 569-A and reaffirmed the methodology previously adopted in Opinion No. 569-A. The new methodology differs significantly from the methodology proposed by FERC in its October 16, 2018 order to determine the NETOs' base ROEs in its four pending cases. FERC Opinion Nos. 569-A and 569-B were appealed to the Court. On August 9, 2022, the Court issued its decision vacating MISO ROE FERC Opinion Nos. 569, 569-A and 569-B and remanded to FERC to reopen the proceedings. The Court found that FERC’s development of the new return methodology was arbitrary and capricious due to FERC’s failure to offer a reasonable explanation for its decision to reintroduce the risk-premium financial model in its new methodology for calculating a just and reasonable return. At this time, Eversource cannot predict how and when FERC will address the Court’s findings on the remand of the MISO FERC opinions or any potential associated impact on the NETOs’ four pending ROE complaint cases.

Given the significant uncertainty regarding the applicability of the FERC opinions in the 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 at this time. As well, Eversource cannot reasonably estimate a range of 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.

A change of 10 basis 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.

XML

FAIR VALUE OF FINANCIAL INSTRUMENTS

3 Months Ended

Mar. 31, 2023

Fair Value Disclosures [Abstract]

FAIR VALUE OF FINANCIAL INSTRUMENTS

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
(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
As of March 31, 2023:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	137.1	$	116.2	$	100.8	$	43.0	$	36.3	$	—	$	—
Long-Term Debt	22,178.0		20,650.5		4,310.2		4,096.9		4,426.0		4,217.4		1,459.4		1,331.7
Rate Reduction Bonds	432.1		417.3		—		—		—		—		432.1		417.3
As of December 31, 2022:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	136.7	$	116.2	$	99.2	$	43.0	$	37.5	$	—	$	—
Long-Term Debt	21,044.1		18,891.3		4,216.5		3,828.3		4,425.1		4,091.8		1,164.6		970.5
Rate Reduction Bonds	453.7		424.7		—		—		—		—		453.7		424.7

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 1C, "Summary of Significant Accounting Policies – Fair Value Measurements," for the fair value measurement policy and the fair value hierarchy.

XML

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

3 Months Ended

Mar. 31, 2023

Equity [Abstract]

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)

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

	For the Three Months Ended March 31, 2023								For the Three Months Ended March 31, 2022
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 Gains/(Losses) on Marketable Securities		Defined Benefit Plans		Total
Balance as of Beginning of Period	$	(0.4)	$	(1.2)	$	(37.8)	$	(39.4)	$	(0.4)	$	0.4	$	(42.3)	$	(42.3)
OCI Before Reclassifications	—		—		—		—		—		(0.8)		—		(0.8)
Amounts Reclassified from AOCI	—		1.2		2.0		3.2		—		—		1.5		1.5
Net OCI	—		1.2		2.0		3.2		—		(0.8)		1.5		0.7
Balance as of End of Period	$	(0.4)	$	—	$	(35.8)	$	(36.2)	$	(0.4)	$	(0.4)	$	(40.8)	$	(41.6)

Defined benefit plan OCI amounts reclassified from AOCI relate to the unamortized actuarial gains and losses and prior service costs on the defined benefit plans that are amortized from AOCI into Other Income, Net over the average future employee service period.

XML

COMMON SHARES

3 Months Ended

Mar. 31, 2023

Equity [Abstract]

COMMON SHARES

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
			Authorized as of March 31, 2023 and December 31, 2022	Issued as of
	Par Value			March 31, 2023	December 31, 2022
Eversource	$	5	380,000,000	359,984,073	359,984,073
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

Treasury Shares: As of March 31, 2023 and December 31, 2022, there were 11,175,991 and 11,540,218 Eversource common shares held as treasury shares, respectively. As of March 31, 2023 and December 31, 2022, there were 348,808,082 and 348,443,855 Eversource common shares outstanding, respectively.

Eversource 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. Eversource also issued treasury shares for its October 2022 water business acquisition. 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.

On May 3, 2023, shareholders voted to increase the authorized common shares from 380,000,000 shares to 410,000,000 shares.

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTSDividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for each of the three months ended March 31, 2023 and 2022. 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 March 31, 2023 and December 31, 2022. 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.

XML

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

3 Months Ended

Mar. 31, 2023

Equity [Abstract]

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS

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
			Authorized as of March 31, 2023 and December 31, 2022	Issued as of
	Par Value			March 31, 2023	December 31, 2022
Eversource	$	5	380,000,000	359,984,073	359,984,073
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

Treasury Shares: As of March 31, 2023 and December 31, 2022, there were 11,175,991 and 11,540,218 Eversource common shares held as treasury shares, respectively. As of March 31, 2023 and December 31, 2022, there were 348,808,082 and 348,443,855 Eversource common shares outstanding, respectively.

Eversource 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. Eversource also issued treasury shares for its October 2022 water business acquisition. 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.

On May 3, 2023, shareholders voted to increase the authorized common shares from 380,000,000 shares to 410,000,000 shares.

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTSDividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for each of the three months ended March 31, 2023 and 2022. 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 March 31, 2023 and December 31, 2022. 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.

XML

EARNINGS PER SHARE

3 Months Ended

Mar. 31, 2023

Earnings Per Share [Abstract]

EARNINGS PER SHARE

EARNINGS PER SHARE

Basic EPS is computed based upon the weighted average number of common shares outstanding during each period.  Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards as if they were converted into outstanding common shares.  The dilutive effect of unvested RSU and performance share awards is calculated using the treasury stock method.  RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. For the three months ended March 31, 2023 and 2022, there were no antidilutive share awards excluded from the computation of diluted EPS.

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

Eversource (Millions of Dollars, except share information)	For the Three Months Ended
	March 31, 2023		March 31, 2022
Net Income Attributable to Common Shareholders	$	491.2	$	443.4
Weighted Average Common Shares Outstanding:
Basic	349,217,147		345,156,346
Dilutive Effect	394,866		504,787
Diluted	349,612,013		345,661,133
Basic and Diluted EPS	$	1.41	$	1.28

XML

REVENUES

3 Months Ended

Mar. 31, 2023

Revenue from Contract with Customer [Abstract]

REVENUES

REVENUESThe following tables present operating revenues disaggregated by revenue source:

	For the Three Months Ended March 31, 2023
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	$	1,464.0	$	576.6	$	—	$	28.9	$	—	$	—	$	2,069.5
Commercial	788.4		320.0		—		15.5		—		(1.0)		1,122.9
Industrial	89.1		69.6		—		1.1		—		(5.1)		154.7
Total Retail Tariff Sales Revenues	2,341.5		966.2		—		45.5		—		(6.1)		3,347.1
Wholesale Transmission Revenues	—		—		435.0		—		—		(325.3)		109.7
Wholesale Market Sales Revenues	217.3		49.1		—		0.8		—		—		267.2
Other Revenues from Contracts with Customers	18.3		1.5		4.7		2.1		413.8		(412.6)		27.8
Total Revenues from Contracts with Customers	2,577.1		1,016.8		439.7		48.4		413.8		(744.0)		3,751.8
Alternative Revenue Programs	6.0		27.4		18.7		1.7		—		(16.9)		36.9
Other Revenues	5.5		1.0		0.2		0.2		—		—		6.9
Total Operating Revenues	$	2,588.6	$	1,045.2	$	458.6	$	50.3	$	413.8	$	(760.9)	$	3,795.6

	For the Three Months Ended March 31, 2022
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	$	1,186.2	$	556.8	$	—	$	28.2	$	—	$	—	$	1,771.2
Commercial	661.3		257.6		—		14.6		—		(1.1)		932.4
Industrial	89.6		68.1		—		1.1		—		(4.5)		154.3
Total Retail Tariff Sales Revenues	1,937.1		882.5		—		43.9		—		(5.6)		2,857.9
Wholesale Transmission Revenues	—		—		446.2		—		24.4		(364.7)		105.9
Wholesale Market Sales Revenues	365.5		33.5		—		0.8		—		—		399.8
Other Revenues from Contracts with Customers	17.7		1.0		3.8		1.9		359.1		(353.1)		30.4
Amortization of/(Reserve for)    Revenues Subject to Refund (1)	58.4		—		—		(0.4)		—		—		58.0
Total Revenues from Contracts with Customers	2,378.7		917.0		450.0		46.2		383.5		(723.4)		3,452.0
Alternative Revenue Programs	4.8		10.2		(15.0)		2.2		—		13.6		15.8
Other Revenues	2.8		0.4		0.2		0.1		—		—		3.5
Total Operating Revenues	$	2,386.3	$	927.6	$	435.2	$	48.5	$	383.5	$	(709.8)	$	3,471.3

	For the Three Months Ended March 31, 2023						For the Three Months Ended March 31, 2022
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	762.2	$	467.8	$	234.0	$	599.1	$	404.6	$	182.5
Commercial	295.3		384.3		108.6		242.2		331.3		88.4
Industrial	33.9		32.6		22.6		33.5		34.1		22.0
Total Retail Tariff Sales Revenues	1,091.4		884.7		365.2		874.8		770.0		292.9
Wholesale Transmission Revenues	195.8		167.8		71.4		209.1		165.2		71.9
Wholesale Market Sales Revenues	154.6		41.1		21.6		279.9		57.9		27.7
Other Revenues from Contracts with Customers	9.3		10.8		2.9		7.9		11.6		2.6
Amortization of Revenues Subject to Refund (1)	0.7		—		—		58.4		—		—
Total Revenues from Contracts with Customers	1,451.8		1,104.4		461.1		1,430.1		1,004.7		395.1
Alternative Revenue Programs	24.6		(9.5)		9.6		1.3		(8.2)		(3.3)
Other Revenues	2.2		2.5		1.0		0.1		2.0		0.9
Eliminations	(139.7)		(141.1)		(51.5)		(145.7)		(135.3)		(53.3)
Total Operating Revenues	$	1,338.9	$	956.3	$	420.2	$	1,285.8	$	863.2	$	339.4

(1)    Amortization of/(Reserve for) Revenues Subject to Refund within the Electric Distribution segment in the first quarter of 2022 represents customer credits being distributed to CL&P’s customers on retail electric bills as a result of the October 2021 CL&P settlement agreement and the 2021 civil penalty for non-compliance with storm performance standards. Total customer credits as a result of the 2021 settlement and civil penalty were $93.4 million. The settlement amount of $65 million was refunded over a two-month billing period from December 1, 2021 to January 31, 2022 and the civil penalty of $28.4 million was refunded over a one year billing period, which began September 1, 2021.

XML

SEGMENT INFORMATION

3 Months Ended

Mar. 31, 2023

Segment Reporting [Abstract]

SEGMENT INFORMATION

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 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) the results of other unregulated subsidiaries, which are not part of its core business, and 5) 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., and a renewable energy investment fund that was liquidated in the first quarter of 2023.

In the ordinary course of business, Yankee Gas, NSTAR Gas and EGMA purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline project described above. These affiliate transaction costs total $77.7 million annually and are classified as Purchased Power, Purchased Natural Gas and Transmission on the Eversource statements of income.

Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has one 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 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 income/expense.   

Eversource's segment information is as follows:

	For the Three Months Ended March 31, 2023
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Operating Revenues	$	2,588.6	$	1,045.2	$	458.6	$	50.3	$	413.8	$	(760.9)	$	3,795.6
Depreciation and Amortization	(22.0)		(77.0)		(89.9)		(13.3)		(36.8)		2.1		(236.9)
Other Operating Expenses	(2,342.3)		(730.4)		(128.2)		(27.9)		(339.6)		759.3		(2,809.1)
Operating Income	$	224.3	$	237.8	$	240.5	$	9.1	$	37.4	$	0.5	$	749.6
Interest Expense	$	(69.3)	$	(21.2)	$	(41.5)	$	(9.4)	$	(85.1)	$	32.0	$	(194.5)
Other Income, Net	54.3		9.0		9.4		1.1		565.8		(550.6)		89.0
Net Income Attributable to Common Shareholders	165.5		170.3		155.1		1.5		516.9		(518.1)		491.2
Cash Flows Used for Investments in Plant	371.9		165.5		336.6		37.9		65.2		—		977.1

	For the Three Months Ended March 31, 2022
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Operating Revenues	$	2,386.3	$	927.6	$	435.2	$	48.5	$	383.5	$	(709.8)	$	3,471.3
Depreciation and Amortization	(351.6)		(51.9)		(81.9)		(12.3)		(30.2)		1.6		(526.3)
Other Operating Expenses	(1,845.6)		(657.3)		(129.3)		(27.1)		(331.4)		708.8		(2,281.9)
Operating Income	$	189.1	$	218.4	$	224.0	$	9.1	$	21.9	$	0.6	$	663.1
Interest Expense	$	(59.4)	$	(15.8)	$	(33.2)	$	(8.2)	$	(46.8)	$	10.1	$	(153.3)
Other Income, Net	47.6		10.1		8.9		2.2		495.9		(493.1)		71.6
Net Income Attributable to Common Shareholders	140.9		164.0		148.5		3.7		468.7		(482.4)		443.4
Cash Flows Used for Investments in Plant	280.5		127.3		266.9		27.8		62.1		—		764.6

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 March 31, 2023	$	27,978.8	$	8,127.8	$	13,522.6	$	2,804.2	$	27,186.4	$	(25,514.6)	$	54,105.2
As of December 31, 2022	27,365.0		8,084.9		13,369.5		2,783.8		26,365.2		(24,737.5)		53,230.9

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

3 Months Ended

Mar. 31, 2023

Accounting Policies [Abstract]

Basis of Presentation

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, NSTAR Gas and EGMA (natural gas utilities), and Aquarion (water utilities). Eversource provides energy delivery and/or water service to approximately 4.4 million electric, natural gas and water customers through twelve regulated utilities in Connecticut, Massachusetts and New Hampshire.

The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries.  Intercompany transactions have been eliminated in consolidation.  The accompanying unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P 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 2022 Form 10-K, which was filed with the SEC on February 15, 2023. 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 March 31, 2023 and December 31, 2022, and the results of operations, comprehensive income, common shareholders' equity and cash flows for the three months ended March 31, 2023 and 2022. The results of operations, comprehensive income and cash flows for the three months ended March 31, 2023 and 2022 are not necessarily indicative of the results expected for a full year.  

CYAPC and YAEC are inactive regional nuclear power companies engaged in the long-term storage of their spent nuclear fuel. Eversource consolidates the operations of 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.

Certain reclassifications of prior period data were made in the accompanying financial statements to conform to the current period presentation.

Allowance for Uncollectible Accounts

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). The current expected credit loss (CECL) model is applied to receivables for purposes of calculating the allowance for uncollectible accounts. This 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 an aging-based quantitative assessment that applies an estimated uncollectible percentage to each receivable aging category.  Factors in determining credit loss include historical collection, write-off experience, analysis of delinquency statistics, and management's assessment of collectability from customers, including current economic conditions, customer payment trends, the impact on customer bills because of energy usage trends and changes in rates, flexible payment plans and financial hardship arrearage management programs being offered to customers, reasonable forecasts, and expectations of future collectability and collection efforts. Management continuously assesses the collectability of receivables and adjusts estimates based on actual experience and future expectations based on economic conditions, 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 allowance for uncollectible accounts when the customer accounts are no longer in service and these balances are deemed to be uncollectible. Management concluded that the reserve balance as of March 31, 2023 adequately reflected the collection risk and net realizable value for its receivables.

As of both March 31, 2023 and December 31, 2022, the total amount incurred as a result of COVID-19 included in the allowance for uncollectible accounts was $50.9 million at Eversource, $16.0 million at CL&P, and $4.1 million at NSTAR Electric. At our Connecticut and Massachusetts utilities, the 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 future rates. No COVID-19 related uncollectible amounts were deferred at PSNH as a result of a July 2021 NHPUC order. Based on the status of our COVID-19 regulatory dockets, policies and practices in the jurisdictions in which we operate, we believe the state regulatory commissions in Connecticut and Massachusetts will allow us to recover our incremental uncollectible customer receivable costs associated with COVID-19.

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, NSTAR Gas and EGMA 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. Management uses a higher credit risk profile for this pool of trade receivables as compared to non-hardship receivables. The allowance for uncollectible hardship accounts is included in the total uncollectible allowance balance.

The total allowance for uncollectible accounts is included in Receivables, Net on the balance sheets.

Fair Value Measurements

Fair Value Measurements

Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" (normal) and to 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, equity method investments, AROs, and in the valuation of business combinations and asset acquisitions. The fair value measurement guidance was also applied in estimating the 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. The 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.

Other Taxes

Other TaxesEversource'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 incomeAs 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.

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

3 Months Ended

Mar. 31, 2023

Accounting Policies [Abstract]

Allowance for Uncollectible Accounts

The activity in the allowance for uncollectible accounts by portfolio segment as of March 31st is as follows:

	Eversource						CL&P						NSTAR Electric						PSNH
(Millions of Dollars)	Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Hardship Accounts		Retail (Non-Hardship), Wholesale, and Other		Total Allowance		Total Allowance
Three Months Ended 2023
Beginning Balance	$	284.4	$	201.9	$	486.3	$	188.9	$	36.4	$	225.3	$	43.7	$	51.3	$	95.0	$	29.2
Uncollectible Expense	—		22.8		22.8		—		3.9		3.9		—		4.7		4.7		5.1
Uncollectible Costs Deferred (1)	43.7		14.3		58.0		34.3		2.7		37.0		(1.3)		5.4		4.1		1.2
Write-Offs	(9.7)		(26.3)		(36.0)		(7.3)		(7.0)		(14.3)		(0.4)		(10.3)		(10.7)		(2.2)
Recoveries Collected	0.3		3.7		4.0		0.3		1.2		1.5		—		1.5		1.5		0.2
Ending Balance	$	318.7	$	216.4	$	535.1	$	216.2	$	37.2	$	253.4	$	42.0	$	52.6	$	94.6	$	33.5

Three Months Ended 2022
Beginning Balance	$	226.1	$	191.3	$	417.4	$	144.6	$	36.7	$	181.3	$	43.3	$	53.7	$	97.0	$	24.3
Uncollectible Expense	—		17.1		17.1		—		3.8		3.8		—		4.7		4.7		2.5
Uncollectible Costs Deferred (1)	0.9		14.8		15.7		(4.0)		(2.1)		(6.1)		(3.3)		5.4		2.1		1.0
Write-Offs	(2.3)		(22.0)		(24.3)		(1.1)		(0.5)		(1.6)		(0.3)		(10.6)		(10.9)		(1.8)
Recoveries Collected	0.8		5.5		6.3		0.6		2.5		3.1		—		1.9		1.9		0.2
Ending Balance	$	225.5	$	206.7	$	432.2	$	140.1	$	40.4	$	180.5	$	39.7	$	55.1	$	94.8	$	26.2

(1) These expected credit losses are deferred as regulatory costs on the balance sheets, as these amounts are ultimately recovered in rates. Amounts include uncollectible costs for hardship accounts and other customer receivables, including uncollectible amounts related to uncollectible energy supply costs and COVID-19. The increase in the allowance for uncollectible hardship accounts in 2023 at Eversource and CL&P primarily relates to increased customer enrollment in disconnection prevention programs in Connecticut.

Components of Other Income, Net

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

	For the Three Months Ended
	March 31, 2023								March 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Pension, SERP and PBOP Non-Service    Income Components, Net of Deferred Portion	$	34.8	$	9.5	$	14.7	$	4.2	$	54.3	$	15.9	$	21.0	$	6.6
AFUDC Equity	15.5		4.1		9.5		0.7		9.9		2.8		4.9		0.4
Equity in Earnings of Unconsolidated Affiliates	3.8		—		0.1		—		0.4		—		—		—
Investment (Loss)/Income	(1.7)		(0.6)		(0.5)		(0.1)		(0.2)		(0.4)		(0.3)		0.2
Interest Income	23.1		1.9		16.0		0.9		6.7		1.3		3.5		0.3
Other	13.5		—		0.1		—		0.5		—		0.1		—
Total Other Income, Net	$	89.0	$	14.9	$	39.9	$	5.7	$	71.6	$	19.6	$	29.2	$	7.5

Investments in Unconsolidated Affiliates

Eversource's investments included the following:

			Investment Balance
(Millions of Dollars)	Ownership Interest		As of March 31, 2023		As of December 31, 2022
Offshore Wind Business - North East Offshore	50	%	$	2,159.2	$	1,947.1
Natural Gas Pipeline - Algonquin Gas Transmission, LLC	15	%	117.5		118.8
Renewable Energy Investment Fund	90	%	—		84.1
Other	various		26.2		26.1
Total Investments in Unconsolidated Affiliates			$	2,302.9	$	2,176.1

Other Taxes

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
(Millions of Dollars)	March 31, 2023		March 31, 2022
Eversource	$	55.0	$	48.6
CL&P	43.1		37.8

Non-cash Investing Activities

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

(Millions of Dollars)	As of March 31, 2023		As of March 31, 2022
Eversource	$	400.8	$	385.6
CL&P	101.9		102.1
NSTAR Electric	117.4		85.8
PSNH	54.6		49.5

Reconciliation of Cash Balances to Cash and Restricted Cash

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 March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Cash and Cash Equivalents as reported on the Balance Sheets	$	36.0	$	9.3	$	0.6	$	0.1	$	374.6	$	11.3	$	327.7	$	0.1
Restricted cash included in:
Special Deposits	89.0		8.9		17.8		19.5		102.2		8.8		17.5		33.1
Marketable Securities	17.9		0.2		—		0.2		25.4		0.2		0.1		0.4
Other Long-Term Assets	19.9		—		—		3.2		19.6		—		—		3.2
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows	$	162.8	$	18.4	$	18.4	$	23.0	$	521.8	$	20.3	$	345.3	$	36.8

XML

REGULATORY ACCOUNTING (Tables)

3 Months Ended

Mar. 31, 2023

Regulated Operations [Abstract]

Components of Regulatory Assets

The components of regulatory assets were as follows:

	As of March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Storm Costs, Net	$	1,658.7	$	889.2	$	564.9	$	204.6	$	1,379.1	$	799.3	$	484.4	$	95.4
Regulatory Tracking Mechanisms	1,028.7		228.2		432.4		122.8		1,075.3		216.8		391.5		73.7
Benefit Costs	910.3		155.6		294.4		56.1		921.7		156.7		299.5		56.6
Income Taxes, Net	856.1		492.9		118.1		13.1		853.3		491.1		115.6		16.0
Securitized Stranded Costs	424.9		—		—		424.9		435.7		—		—		435.7
Goodwill-related	276.7		—		237.6		—		281.0		—		241.2		—
Derivative Liabilities	168.8		168.8		—		—		181.8		181.8		—		—
Asset Retirement Obligations	129.2		36.5		68.0		4.5		127.9		35.9		68.2		4.4
Other Regulatory Assets	286.5		25.3		107.9		12.5		322.5		26.2		114.0		14.4
Total Regulatory Assets	5,739.9		1,996.5		1,823.3		838.5		5,578.3		1,907.8		1,714.4		696.2
Less:  Current Portion	1,332.0		356.5		559.8		140.9		1,335.5		314.1		492.8		102.2
Total Long-Term Regulatory Assets	$	4,407.9	$	1,640.0	$	1,263.5	$	697.6	$	4,242.8	$	1,593.7	$	1,221.6	$	594.0

Components of Regulatory Liabilities

The components of regulatory liabilities were as follows:

	As of March 31, 2023								As of December 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
EDIT due to Tax Cuts and Jobs Act of 2017	$	2,601.8	$	980.0	$	933.9	$	346.1	$	2,619.3	$	983.6	$	944.3	$	348.6
Cost of Removal	705.4		144.2		412.9		20.2		670.6		130.8		405.3		14.7
Regulatory Tracking Mechanisms	653.6		145.0		341.6		73.2		890.8		361.0		336.1		155.0
Deferred Portion of Non-Service Income    Components of Pension, SERP and PBOP	291.4		38.3		148.5		30.8		270.9		34.5		139.7		28.8
AFUDC - Transmission	103.8		49.8		54.0		—		98.2		48.2		50.0		—
Benefit Costs	49.2		0.6		27.1		—		55.4		0.7		31.4		—
Other Regulatory Liabilities	219.7		44.0		14.6		6.6		215.9		40.6		14.5		6.5
Total Regulatory Liabilities	4,624.9		1,401.9		1,932.6		476.9		4,821.1		1,599.4		1,921.3		553.6
Less:  Current Portion	650.5		124.6		375.0		86.6		890.8		336.0		373.2		162.0
Total Long-Term Regulatory Liabilities	$	3,974.4	$	1,277.3	$	1,557.6	$	390.3	$	3,930.3	$	1,263.4	$	1,548.1	$	391.6

XML

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION (Tables)

3 Months Ended

Mar. 31, 2023

Property, Plant and Equipment [Abstract]

Summary of Property, Plant, and Equipment

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

Eversource	As of March 31, 2023		As of December 31, 2022
(Millions of Dollars)
Distribution - Electric	$	18,618.6	$	18,326.2
Distribution - Natural Gas	7,562.8		7,443.8
Transmission - Electric	13,884.0		13,709.3
Distribution - Water	2,122.5		2,112.6
Solar	200.8		200.8
Utility	42,388.7		41,792.7
Other (1)	1,791.7		1,738.1
Property, Plant and Equipment, Gross	44,180.4		43,530.8
Less:  Accumulated Depreciation
Utility	(9,317.7)		(9,167.4)
Other	(744.7)		(706.1)
Total Accumulated Depreciation	(10,062.4)		(9,873.5)
Property, Plant and Equipment, Net	34,118.0		33,657.3
Construction Work in Progress	2,626.9		2,455.5
Total Property, Plant and Equipment, Net	$	36,744.9	$	36,112.8

	As of March 31, 2023						As of December 31, 2022
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Distribution - Electric	$	7,510.8	$	8,516.7	$	2,631.4	$	7,370.1	$	8,410.0	$	2,586.4
Transmission - Electric	6,235.2		5,382.8		2,267.6		6,165.1		5,333.8		2,212.0
Solar	—		200.8		—		—		200.8		—
Property, Plant and Equipment, Gross	13,746.0		14,100.3		4,899.0		13,535.2		13,944.6		4,798.4
Less:  Accumulated Depreciation	(2,610.4)		(3,429.3)		(940.0)		(2,567.1)		(3,381.2)		(912.3)
Property, Plant and Equipment, Net	11,135.6		10,671.0		3,959.0		10,968.1		10,563.4		3,886.1
Construction Work in Progress	494.7		1,148.0		189.0		498.9		1,063.6		174.1
Total Property, Plant and Equipment, Net	$	11,630.3	$	11,819.0	$	4,148.0	$	11,467.0	$	11,627.0	$	4,060.2

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

XML

DERIVATIVE INSTRUMENTS (Tables)

3 Months Ended

Mar. 31, 2023

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Gross Fair Values and Net Amounts of Contracts

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 March 31, 2023						As of December 31, 2022
CL&P (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
Current Derivative Assets	Level 3	$	17.0	$	(0.5)	$	16.5	$	16.3	$	(0.5)	$	15.8
Long-Term Derivative Assets	Level 3	24.9		(0.8)		24.1		28.8		(0.9)		27.9
Current Derivative Liabilities	Level 3	(85.1)		—		(85.1)		(81.6)		—		(81.6)
Long-Term Derivative Liabilities	Level 3	(124.3)		—		(124.3)		(143.9)		—		(143.9)

    

(1)    Amounts represent derivative assets and liabilities that Eversource elected to record net on the balance sheets.  These amounts are subject to master netting agreements or similar agreements for which the right of offset exists.

Summary of Level 3 Derivative Contracts and Significant Unobservable Inputs Used

The following is a summary of the significant unobservable inputs utilized in the valuations of the derivative contracts classified as Level 3:

	As of March 31, 2023								As of December 31, 2022
CL&P	Range				Average			Period Covered	Range				Average			Period Covered
Forward Reserve Prices	$	0.44	—	$0.50	$	0.47	per kW-Month	2023 - 2024	$	0.44	—	$0.50	$	0.47	per kW-Month	2023 - 2024

Changes in the Level 3 Category of Derivative Assets Measured at Fair Value on a Recurring Basis

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 March 31,
(Millions of Dollars)	2023		2022
Derivatives, Net:
Fair Value as of Beginning of Period	$	(181.8)	$	(249.2)
Net Realized/Unrealized (Losses)/Gains Included in Regulatory Assets	(1.9)		6.2
Settlements	14.9		13.6
Fair Value as of End of Period	$	(168.8)	$	(229.4)

XML

MARKETABLE SECURITIES (Tables)

3 Months Ended

Mar. 31, 2023

Investments, Debt and Equity Securities [Abstract]

Summary of Available-for-Sale Debt Securities

The following is a summary of the available-for-sale debt securities:

	As of March 31, 2023								As of December 31, 2022
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
Debt Securities	$	196.5	$	0.2	$	(14.8)	$	181.9	$	201.6	$	0.1	$	(16.2)	$	185.5

Contractual Maturities of Available-for-Sale Debt Securities

As of March 31, 2023, the contractual maturities of available-for-sale debt securities were as follows:

 

Eversource (Millions of Dollars)	Amortized Cost		Fair Value
Less than one year (1)	$	39.8	$	38.9
One to five years	42.5		41.1
Six to ten years	35.6		32.8
Greater than ten years	78.6		69.1
Total Debt Securities	$	196.5	$	181.9

(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. Amounts also include securities in Eversource’s non-qualified executive benefit trust, which are intended to be sold in 2023.

Marketable Securities Recorded at Fair Value on a Recurring Basis by Level

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 March 31, 2023		As of December 31, 2022
Level 1:
Mutual Funds and Equities	$	190.5	$	190.1
Money Market Funds	17.9		25.4
Total Level 1	$	208.4	$	215.5
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury)	$	91.5	$	82.3
Corporate Debt Securities	44.2		46.1
Asset-Backed Debt Securities	8.5		8.6
Municipal Bonds	9.2		12.7
Other Fixed Income Securities	10.6		10.4
Total Level 2	$	164.0	$	160.1
Total Marketable Securities	$	372.4	$	375.6

XML

SHORT-TERM AND LONG-TERM DEBT (Tables)

3 Months Ended

Mar. 31, 2023

Debt Disclosure [Abstract]

Borrowings Outstanding and Available under the Commercial Paper Programs

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
	March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022		March 31, 2023		December 31, 2022
(Millions of Dollars)
Eversource Parent Commercial Paper Program	$	1,048.0	$	1,442.2	$	952.0	$	557.8	5.22	%	4.63	%
NSTAR Electric Commercial Paper Program	147.5		—		502.5		650.0		4.77	%	—	%

Summary of Long-Term Debt Issuance and Repayments

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

(Millions of Dollars)	Interest Rate		Issuance/(Repayment)		Issue Date or Repayment Date	Maturity Date	Use of Proceeds for Issuance/ Repayment Information
CL&P 2023 Series A First Mortgage Bonds	5.25	%	$	500.0	January 2023	January 2053	Repaid 2013 Series A Bonds at maturity and short-term debt, and paid capital expenditures and working capital
CL&P 2013 Series A First Mortgage Bonds	2.50	%	(400.0)		January 2023	January 2023	Paid at maturity
PSNH Series W First Mortgage Bonds	5.15	%	300.0		January 2023	January 2053	Repaid short-term debt, paid capital expenditures and working capital
Eversource Parent Series Z Senior Notes	5.45	%	750.0		March 2023	March 2028	Repaid Series F Senior Notes at maturity and short-term debt
Eversource Parent Series F Senior Notes	2.80	%	(450.0)		May 2023	May 2023	Paid at maturity

XML

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES (Tables)

3 Months Ended

Mar. 31, 2023

Rate Reduction Bonds and Variable Interest Entity [Abstract]

Summary of the Impact of Funding on the Balance Sheets and Income Statements

The following tables summarize the impact of PSNH Funding on PSNH's balance sheets and income statements:

(Millions of Dollars)
PSNH Balance Sheets:	As of March 31, 2023		As of December 31, 2022
Restricted Cash - Current Portion (included in Current Assets)	$	18.7	$	32.4
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2
Securitized Stranded Cost (included in Regulatory Assets)	424.9		435.7
Other Regulatory Liabilities (included in Regulatory Liabilities)	8.8		6.0
Accrued Interest (included in Other Current Liabilities)	2.7		6.9
Rate Reduction Bonds - Current Portion	43.2		43.2
Rate Reduction Bonds - Long-Term Portion	388.9		410.5

(Millions of Dollars) PSNH Income Statements:	For the Three Months Ended
	March 31, 2023		March 31, 2022
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	$	10.8	$	10.8
Interest Expense on RRB Principal (included in Interest Expense)	4.1		4.4

XML

PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION (Tables)

3 Months Ended

Mar. 31, 2023

Postemployment Benefits [Abstract]

Components of Net Periodic Benefit Expense/(Income)

Pension, SERP and PBOP expense reflected in the statements of cash flows for CL&P, NSTAR Electric and PSNH does not include intercompany allocations of net periodic benefit plan expense/(income), as these amounts are cash settled on a short-term basis.

	Pension and SERP								PBOP
	For the Three Months Ended March 31, 2023								For the Three Months Ended March 31, 2023
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Service Cost	$	11.0	$	3.0	$	2.1	$	1.1	$	1.8	$	0.3	$	0.3	$	0.2
Interest Cost	63.7		12.6		13.5		6.8		8.5		1.6		2.3		0.9
Expected Return on Plan Assets	(115.9)		(23.4)		(28.4)		(12.3)		(19.1)		(2.4)		(9.2)		(1.4)
Actuarial Loss	12.5		0.8		4.9		0.4		—		—		—		—
Prior Service Cost/(Credit)	0.3		—		0.1		—		(5.4)		0.3		(4.2)		0.1
Total Net Periodic Benefit Plan Income	$	(28.4)	$	(7.0)	$	(7.8)	$	(4.0)	$	(14.2)	$	(0.2)	$	(10.8)	$	(0.2)
Intercompany Income Allocations	N/A		$	(2.0)	$	(1.7)	$	(0.5)	N/A		$	(0.5)	$	(0.6)	$	(0.2)
	Pension and SERP								PBOP
	For the Three Months Ended March 31, 2022								For the Three Months Ended March 31, 2022
(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Service Cost	$	17.7	$	4.5	$	3.6	$	1.8	$	2.8	$	0.5	$	0.5	$	0.2
Interest Cost	38.6		7.8		8.1		4.2		5.0		0.9		1.3		0.5
Expected Return on Plan Assets	(131.7)		(26.6)		(32.0)		(14.1)		(22.4)		(2.8)		(10.6)		(1.6)
Actuarial Loss	30.7		4.2		8.5		2.2		—		—		—		—
Prior Service Cost/(Credit)	0.4		—		0.1		—		(5.4)		0.2		(4.3)		0.1
Total Net Periodic Benefit Plan Income	$	(44.3)	$	(10.1)	$	(11.7)	$	(5.9)	$	(20.0)	$	(1.2)	$	(13.1)	$	(0.8)
Intercompany Income Allocations	N/A		$	(3.8)	$	(2.9)	$	(0.8)	N/A		$	(0.9)	$	(0.9)	$	(0.3)

XML

COMMITMENTS AND CONTINGENCIES (Tables)

3 Months Ended

Mar. 31, 2023

Commitments and Contingencies Disclosure [Abstract]

Environmental Sites and Related Reserves

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 March 31, 2023			As of December 31, 2022
	Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)
Eversource	59	$	121.2	59	$	122.6
CL&P	13	13.6		13	13.9
NSTAR Electric	10	3.4		10	3.4
PSNH	8	6.1		8	6.1

Summary of Exposure to Guarantees and Indemnifications

The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries and affiliates to external parties, and primarily relates to its offshore wind business:  

As of March 31, 2023
Company (Obligor)	Description	Maximum Exposure (in millions)		Expiration Dates
North East Offshore LLC	Construction-related purchase agreements with third-party contractors (1)	$	726.2	(1)
Sunrise Wind LLC	Construction-related purchase agreements with third-party contractors (2)	668.6		2025 - 2028
Revolution Wind, LLC	Construction-related purchase agreements with third-party contractors (3)	409.7		2024 - 2027
South Fork Wind, LLC	Construction-related purchase agreements with third-party contractors (4)	126.2		2023 - 2026
Eversource Investment LLC	Funding and indemnification obligations of North East Offshore LLC (5)	68.9		(5)
South Fork Wind, LLC	Power Purchase Agreement Security (6)	7.1		(6)
Sunrise Wind LLC	OREC capacity production (7)	11.0		(7)
Bay State Wind LLC	Real estate purchase	2.5		2023
South Fork Wind, LLC	Transmission interconnection	1.2		—
Eversource Investment LLC	Letters of Credit (8)	4.3		—
Various	Surety bonds (9)	37.2		2023 - 2024
Eversource Service	Lease payments for real estate	0.4		2024

(1)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, North East Offshore LLC (NEO), under which Eversource parent agreed to guarantee 50 percent of NEO’s performance of obligations under certain purchase agreements with third-party contractors, in an aggregate amount not to exceed $1.3 billion with an expiration date in 2025. Eversource parent also issued a separate guarantee to Ørsted on behalf of NEO, under which Eversource parent agreed to guarantee 50 percent of NEO’s payment obligations under certain offshore wind project construction-related agreements with Ørsted in an aggregate amount not to exceed $62.5 million and expiring upon full performance of the guaranteed obligation. Any amounts paid under this guarantee to Ørsted will count toward, but not increase, the maximum amount of the Funding Guarantee described in Note 5, below.

(2)     Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guarantee Sunrise Wind LLC's performance of certain obligations, in an aggregate amount not to exceed $838.4 million, in connection with construction-related purchase agreements. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging from March 2025 and October 2028 and (ii) full performance of the guaranteed obligations.     

(3)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, Revolution Wind, LLC, whereby Eversource parent will guarantee Revolution Wind, LLC's performance of certain obligations, in an aggregate amount not to exceed $547.1 million, in connection with construction-related purchase agreements. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging from May 2024 and November 2027 and (ii) full performance of the guaranteed obligations.

(4)    Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, South Fork Wind, LLC, whereby Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations in connection with construction-related purchase agreements. Under these guarantees, Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations, in a total aggregate amount not to exceed $207.7 million. Eversource parent’s obligations under these guarantees expire upon the earlier of (i) dates ranging from June 2023 and August 2026 and (ii) full performance of the guaranteed obligations.

(5)    Eversource parent issued a guarantee (Funding Guarantee) on behalf of Eversource Investment LLC (EI), its wholly-owned subsidiary that holds a 50 percent ownership interest in NEO, under which Eversource parent agreed to guarantee certain funding obligations and certain indemnification payments of EI under the operating agreement of NEO, in an amount not to exceed $910 million. The guaranteed obligations include payment of EI's funding obligations during the construction phase of NEO’s underlying offshore wind projects and indemnification obligations associated with third party credit support for its investment in NEO. Eversource parent’s obligations under the Funding Guarantee expire upon the full performance of the guaranteed obligations.

(6)    Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, South Fork Wind, LLC, whereby Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations, in an amount not to exceed $7.1 million, under a Power Purchase Agreement between the Long Island Power Authority and South Fork Wind, LLC (the Agreement). The guarantee expires upon the later of (i) the end of the Agreement term and (ii) full performance of the guaranteed obligations.

(7)    Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guarantee 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 by and between the New York State Energy Research and Development Authority (NYSERDA) and Sunrise Wind LLC. The guarantee expires upon the full performance of the guaranteed obligations.

(8)    On September 16, 2020, Eversource parent entered into a guarantee on behalf of EI, which holds Eversource's investments in offshore wind-related equity method investments, under which Eversource parent would guarantee EI's obligations under a letter of credit facility with a financial institution that EI may request in an aggregate amount of up to approximately $25 million. In January 2022, EI issued two letters of credit on behalf of South Fork Wind, LLC related to future decommissioning obligations of certain onshore transmission assets totaling $4.3 million.

(9)    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.

XML

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

3 Months Ended

Mar. 31, 2023

Fair Value Disclosures [Abstract]

Carrying Amounts and Estimated Fair Values of Financial Instruments

Carrying amounts and estimated fair values are as follows:

	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
As of March 31, 2023:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	137.1	$	116.2	$	100.8	$	43.0	$	36.3	$	—	$	—
Long-Term Debt	22,178.0		20,650.5		4,310.2		4,096.9		4,426.0		4,217.4		1,459.4		1,331.7
Rate Reduction Bonds	432.1		417.3		—		—		—		—		432.1		417.3
As of December 31, 2022:
Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	136.7	$	116.2	$	99.2	$	43.0	$	37.5	$	—	$	—
Long-Term Debt	21,044.1		18,891.3		4,216.5		3,828.3		4,425.1		4,091.8		1,164.6		970.5
Rate Reduction Bonds	453.7		424.7		—		—		—		—		453.7		424.7

XML

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) (Tables)

3 Months Ended

Mar. 31, 2023

Equity [Abstract]

Changes in Accumulated Other Comprehensive Income/(Loss) by Component, Net of Tax

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

	For the Three Months Ended March 31, 2023								For the Three Months Ended March 31, 2022
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 Gains/(Losses) on Marketable Securities		Defined Benefit Plans		Total
Balance as of Beginning of Period	$	(0.4)	$	(1.2)	$	(37.8)	$	(39.4)	$	(0.4)	$	0.4	$	(42.3)	$	(42.3)
OCI Before Reclassifications	—		—		—		—		—		(0.8)		—		(0.8)
Amounts Reclassified from AOCI	—		1.2		2.0		3.2		—		—		1.5		1.5
Net OCI	—		1.2		2.0		3.2		—		(0.8)		1.5		0.7
Balance as of End of Period	$	(0.4)	$	—	$	(35.8)	$	(36.2)	$	(0.4)	$	(0.4)	$	(40.8)	$	(41.6)

XML

COMMON SHARES (Tables)

3 Months Ended

Mar. 31, 2023

Equity [Abstract]

Common Shares Authorized and Issued

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
			Authorized as of March 31, 2023 and December 31, 2022	Issued as of
	Par Value			March 31, 2023	December 31, 2022
Eversource	$	5	380,000,000	359,984,073	359,984,073
CL&P	$	10	24,500,000	6,035,205	6,035,205
NSTAR Electric	$	1	100,000,000	200	200
PSNH	$	1	100,000,000	301	301

XML

EARNINGS PER SHARE (Tables)

3 Months Ended

Mar. 31, 2023

Earnings Per Share [Abstract]

Components of Basic and Diluted EPS

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

Eversource (Millions of Dollars, except share information)	For the Three Months Ended
	March 31, 2023		March 31, 2022
Net Income Attributable to Common Shareholders	$	491.2	$	443.4
Weighted Average Common Shares Outstanding:
Basic	349,217,147		345,156,346
Dilutive Effect	394,866		504,787
Diluted	349,612,013		345,661,133
Basic and Diluted EPS	$	1.41	$	1.28

XML

REVENUES (Tables)

3 Months Ended

Mar. 31, 2023

Revenue from Contract with Customer [Abstract]

Operating Revenues Disaggregated by Revenue Source

The following tables present operating revenues disaggregated by revenue source:

	For the Three Months Ended March 31, 2023
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	$	1,464.0	$	576.6	$	—	$	28.9	$	—	$	—	$	2,069.5
Commercial	788.4		320.0		—		15.5		—		(1.0)		1,122.9
Industrial	89.1		69.6		—		1.1		—		(5.1)		154.7
Total Retail Tariff Sales Revenues	2,341.5		966.2		—		45.5		—		(6.1)		3,347.1
Wholesale Transmission Revenues	—		—		435.0		—		—		(325.3)		109.7
Wholesale Market Sales Revenues	217.3		49.1		—		0.8		—		—		267.2
Other Revenues from Contracts with Customers	18.3		1.5		4.7		2.1		413.8		(412.6)		27.8
Total Revenues from Contracts with Customers	2,577.1		1,016.8		439.7		48.4		413.8		(744.0)		3,751.8
Alternative Revenue Programs	6.0		27.4		18.7		1.7		—		(16.9)		36.9
Other Revenues	5.5		1.0		0.2		0.2		—		—		6.9
Total Operating Revenues	$	2,588.6	$	1,045.2	$	458.6	$	50.3	$	413.8	$	(760.9)	$	3,795.6

	For the Three Months Ended March 31, 2022
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	$	1,186.2	$	556.8	$	—	$	28.2	$	—	$	—	$	1,771.2
Commercial	661.3		257.6		—		14.6		—		(1.1)		932.4
Industrial	89.6		68.1		—		1.1		—		(4.5)		154.3
Total Retail Tariff Sales Revenues	1,937.1		882.5		—		43.9		—		(5.6)		2,857.9
Wholesale Transmission Revenues	—		—		446.2		—		24.4		(364.7)		105.9
Wholesale Market Sales Revenues	365.5		33.5		—		0.8		—		—		399.8
Other Revenues from Contracts with Customers	17.7		1.0		3.8		1.9		359.1		(353.1)		30.4
Amortization of/(Reserve for)    Revenues Subject to Refund (1)	58.4		—		—		(0.4)		—		—		58.0
Total Revenues from Contracts with Customers	2,378.7		917.0		450.0		46.2		383.5		(723.4)		3,452.0
Alternative Revenue Programs	4.8		10.2		(15.0)		2.2		—		13.6		15.8
Other Revenues	2.8		0.4		0.2		0.1		—		—		3.5
Total Operating Revenues	$	2,386.3	$	927.6	$	435.2	$	48.5	$	383.5	$	(709.8)	$	3,471.3

	For the Three Months Ended March 31, 2023						For the Three Months Ended March 31, 2022
(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential	$	762.2	$	467.8	$	234.0	$	599.1	$	404.6	$	182.5
Commercial	295.3		384.3		108.6		242.2		331.3		88.4
Industrial	33.9		32.6		22.6		33.5		34.1		22.0
Total Retail Tariff Sales Revenues	1,091.4		884.7		365.2		874.8		770.0		292.9
Wholesale Transmission Revenues	195.8		167.8		71.4		209.1		165.2		71.9
Wholesale Market Sales Revenues	154.6		41.1		21.6		279.9		57.9		27.7
Other Revenues from Contracts with Customers	9.3		10.8		2.9		7.9		11.6		2.6
Amortization of Revenues Subject to Refund (1)	0.7		—		—		58.4		—		—
Total Revenues from Contracts with Customers	1,451.8		1,104.4		461.1		1,430.1		1,004.7		395.1
Alternative Revenue Programs	24.6		(9.5)		9.6		1.3		(8.2)		(3.3)
Other Revenues	2.2		2.5		1.0		0.1		2.0		0.9
Eliminations	(139.7)		(141.1)		(51.5)		(145.7)		(135.3)		(53.3)
Total Operating Revenues	$	1,338.9	$	956.3	$	420.2	$	1,285.8	$	863.2	$	339.4

(1)    Amortization of/(Reserve for) Revenues Subject to Refund within the Electric Distribution segment in the first quarter of 2022 represents customer credits being distributed to CL&P’s customers on retail electric bills as a result of the October 2021 CL&P settlement agreement and the 2021 civil penalty for non-compliance with storm performance standards. Total customer credits as a result of the 2021 settlement and civil penalty were $93.4 million. The settlement amount of $65 million was refunded over a two-month billing period from December 1, 2021 to January 31, 2022 and the civil penalty of $28.4 million was refunded over a one year billing period, which began September 1, 2021.

XML

SEGMENT INFORMATION (Tables)

3 Months Ended

Mar. 31, 2023

Segment Reporting [Abstract]

Summary of Segment Information and Segmented Total Assets

Eversource's segment information is as follows:

	For the Three Months Ended March 31, 2023
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Operating Revenues	$	2,588.6	$	1,045.2	$	458.6	$	50.3	$	413.8	$	(760.9)	$	3,795.6
Depreciation and Amortization	(22.0)		(77.0)		(89.9)		(13.3)		(36.8)		2.1		(236.9)
Other Operating Expenses	(2,342.3)		(730.4)		(128.2)		(27.9)		(339.6)		759.3		(2,809.1)
Operating Income	$	224.3	$	237.8	$	240.5	$	9.1	$	37.4	$	0.5	$	749.6
Interest Expense	$	(69.3)	$	(21.2)	$	(41.5)	$	(9.4)	$	(85.1)	$	32.0	$	(194.5)
Other Income, Net	54.3		9.0		9.4		1.1		565.8		(550.6)		89.0
Net Income Attributable to Common Shareholders	165.5		170.3		155.1		1.5		516.9		(518.1)		491.2
Cash Flows Used for Investments in Plant	371.9		165.5		336.6		37.9		65.2		—		977.1

	For the Three Months Ended March 31, 2022
Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Operating Revenues	$	2,386.3	$	927.6	$	435.2	$	48.5	$	383.5	$	(709.8)	$	3,471.3
Depreciation and Amortization	(351.6)		(51.9)		(81.9)		(12.3)		(30.2)		1.6		(526.3)
Other Operating Expenses	(1,845.6)		(657.3)		(129.3)		(27.1)		(331.4)		708.8		(2,281.9)
Operating Income	$	189.1	$	218.4	$	224.0	$	9.1	$	21.9	$	0.6	$	663.1
Interest Expense	$	(59.4)	$	(15.8)	$	(33.2)	$	(8.2)	$	(46.8)	$	10.1	$	(153.3)
Other Income, Net	47.6		10.1		8.9		2.2		495.9		(493.1)		71.6
Net Income Attributable to Common Shareholders	140.9		164.0		148.5		3.7		468.7		(482.4)		443.4
Cash Flows Used for Investments in Plant	280.5		127.3		266.9		27.8		62.1		—		764.6

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 March 31, 2023	$	27,978.8	$	8,127.8	$	13,522.6	$	2,804.2	$	27,186.4	$	(25,514.6)	$	54,105.2
As of December 31, 2022	27,365.0		8,084.9		13,369.5		2,783.8		26,365.2		(24,737.5)		53,230.9

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Narrative (Details) customer in Millions		3 Months Ended
	Mar. 21, 2023 USD ($)	Mar. 31, 2023 USD ($) regulatedUtility project customer	Dec. 31, 2022 USD ($)	May 04, 2022	Mar. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Summary of Accounting Policies [Line Items]
Number of electric, natural gas and water customers | customer		4.4
Allowance for uncollectible accounts for late fees and other receivable amounts		$ 535,100,000	$ 486,300,000		$ 432,200,000	$ 417,400,000
Number of offshore wind projects | project		3
Energy Relief Fund - Merrimack Valley Programs
Summary of Accounting Policies [Line Items]
Restricted cash, current		$ 20,000,000	20,000,000
Restricted cash, noncurrent		16,700,000	15,900,000
COVID-19
Summary of Accounting Policies [Line Items]
Allowance for uncollectible accounts for late fees and other receivable amounts		50,900,000	50,900,000
CL&P
Summary of Accounting Policies [Line Items]
Allowance for uncollectible accounts for late fees and other receivable amounts		$ 253,400,000	225,300,000		180,500,000	181,300,000
Period of accounts receivable recoverable under financial or medical duress		180 days
CL&P | COVID-19
Summary of Accounting Policies [Line Items]
Allowance for uncollectible accounts for late fees and other receivable amounts		$ 16,000,000	16,000,000
NSTAR Electric
Summary of Accounting Policies [Line Items]
Allowance for uncollectible accounts for late fees and other receivable amounts		94,600,000	95,000,000.0		94,800,000	97,000,000.0
NSTAR Electric | COVID-19
Summary of Accounting Policies [Line Items]
Allowance for uncollectible accounts for late fees and other receivable amounts		4,100,000	4,100,000
PSNH
Summary of Accounting Policies [Line Items]
Allowance for uncollectible accounts for late fees and other receivable amounts		33,500,000	29,200,000		$ 26,200,000	$ 24,300,000
PSNH | COVID-19
Summary of Accounting Policies [Line Items]
Allowance for uncollectible accounts for late fees and other receivable amounts		$ 0	$ 0
Yankee Gas
Summary of Accounting Policies [Line Items]
Period of accounts receivable recoverable under financial or medical duress		90 days
Connecticut, Massachusetts and New Hampshire
Summary of Accounting Policies [Line Items]
Number of regulated utilities | regulatedUtility		12
Offshore Wind Business
Summary of Accounting Policies [Line Items]
Ownership interest (percent)				50.00%
North East Offshore LLC
Summary of Accounting Policies [Line Items]
Ownership interest (percent)		50.00%
Renewable Energy Investment Fund
Summary of Accounting Policies [Line Items]
Ownership interest (percent)		90.00%
Proceeds from sale of equity method investments	$ 123,400,000
Renewable Energy Investment Fund | Equity Method Investee
Summary of Accounting Policies [Line Items]
Charitable contributions		$ 20,000,000

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Provision for Uncollectible Accounts (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	$ 486,300	$ 417,400
Uncollectible Expense	22,821	17,135
Uncollectible Costs Deferred	58,000	15,700
Write-Offs	(36,000)	(24,300)
Recoveries Collected	4,000	6,300
Ending Balance	535,100	432,200
CL&P
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	225,300	181,300
Uncollectible Expense	3,876	3,776
Uncollectible Costs Deferred	37,000	(6,100)
Write-Offs	(14,300)	(1,600)
Recoveries Collected	1,500	3,100
Ending Balance	253,400	180,500
NSTAR Electric
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	95,000	97,000
Uncollectible Expense	4,697	4,662
Uncollectible Costs Deferred	4,100	2,100
Write-Offs	(10,700)	(10,900)
Recoveries Collected	1,500	1,900
Ending Balance	94,600	94,800
PSNH
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	29,200	24,300
Uncollectible Expense	5,060	2,496
Uncollectible Costs Deferred	1,200	1,000
Write-Offs	(2,200)	(1,800)
Recoveries Collected	200	200
Ending Balance	33,500	26,200
Hardship Accounts
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	284,400	226,100
Uncollectible Expense	0	0
Uncollectible Costs Deferred	43,700	900
Write-Offs	(9,700)	(2,300)
Recoveries Collected	300	800
Ending Balance	318,700	225,500
Hardship Accounts | CL&P
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	188,900	144,600
Uncollectible Expense	0	0
Uncollectible Costs Deferred	34,300	(4,000)
Write-Offs	(7,300)	(1,100)
Recoveries Collected	300	600
Ending Balance	216,200	140,100
Hardship Accounts | NSTAR Electric
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	43,700	43,300
Uncollectible Expense	0	0
Uncollectible Costs Deferred	(1,300)	(3,300)
Write-Offs	(400)	(300)
Recoveries Collected	0	0
Ending Balance	42,000	39,700
Retail (Non-Hardship), Wholesale, and Other
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	201,900	191,300
Uncollectible Expense	22,800	17,100
Uncollectible Costs Deferred	14,300	14,800
Write-Offs	(26,300)	(22,000)
Recoveries Collected	3,700	5,500
Ending Balance	216,400	206,700
Retail (Non-Hardship), Wholesale, and Other | CL&P
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	36,400	36,700
Uncollectible Expense	3,900	3,800
Uncollectible Costs Deferred	2,700	(2,100)
Write-Offs	(7,000)	(500)
Recoveries Collected	1,200	2,500
Ending Balance	37,200	40,400
Retail (Non-Hardship), Wholesale, and Other | NSTAR Electric
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Beginning Balance	51,300	53,700
Uncollectible Expense	4,700	4,700
Uncollectible Costs Deferred	5,400	5,400
Write-Offs	(10,300)	(10,600)
Recoveries Collected	1,500	1,900
Ending Balance	$ 52,600	$ 55,100

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Components of Other Income, Net (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Summary of Accounting Policies [Line Items]
Other income, net	$ 88,981	$ 71,561
Pension, SERP and PBOP Non-Service   Income Components, Net of Deferred Portion
Summary of Accounting Policies [Line Items]
Other income, net	34,800	54,300
AFUDC Equity
Summary of Accounting Policies [Line Items]
Other income, net	15,500	9,900
Equity in Earnings of Unconsolidated Affiliates
Summary of Accounting Policies [Line Items]
Other income, net	3,800	400
Investment Income/(Loss)
Summary of Accounting Policies [Line Items]
Other income, net	(1,700)	(200)
Interest Income
Summary of Accounting Policies [Line Items]
Other income, net	23,100	6,700
Other
Summary of Accounting Policies [Line Items]
Other income, net	13,500	500
CL&P
Summary of Accounting Policies [Line Items]
Other income, net	14,937	19,564
CL&P | Pension, SERP and PBOP Non-Service   Income Components, Net of Deferred Portion
Summary of Accounting Policies [Line Items]
Other income, net	9,500	15,900
CL&P | AFUDC Equity
Summary of Accounting Policies [Line Items]
Other income, net	4,100	2,800
CL&P | Equity in Earnings of Unconsolidated Affiliates
Summary of Accounting Policies [Line Items]
Other income, net	0	0
CL&P | Investment Income/(Loss)
Summary of Accounting Policies [Line Items]
Other income, net	(600)	(400)
CL&P | Interest Income
Summary of Accounting Policies [Line Items]
Other income, net	1,900	1,300
CL&P | Other
Summary of Accounting Policies [Line Items]
Other income, net	0	0
NSTAR Electric
Summary of Accounting Policies [Line Items]
Other income, net	39,873	29,231
NSTAR Electric | Pension, SERP and PBOP Non-Service   Income Components, Net of Deferred Portion
Summary of Accounting Policies [Line Items]
Other income, net	14,700	21,000
NSTAR Electric | AFUDC Equity
Summary of Accounting Policies [Line Items]
Other income, net	9,500	4,900
NSTAR Electric | Equity in Earnings of Unconsolidated Affiliates
Summary of Accounting Policies [Line Items]
Other income, net	100	0
NSTAR Electric | Investment Income/(Loss)
Summary of Accounting Policies [Line Items]
Other income, net	(500)	(300)
NSTAR Electric | Interest Income
Summary of Accounting Policies [Line Items]
Other income, net	16,000	3,500
NSTAR Electric | Other
Summary of Accounting Policies [Line Items]
Other income, net	100	100
PSNH
Summary of Accounting Policies [Line Items]
Other income, net	5,717	7,509
PSNH | Pension, SERP and PBOP Non-Service   Income Components, Net of Deferred Portion
Summary of Accounting Policies [Line Items]
Other income, net	4,200	6,600
PSNH | AFUDC Equity
Summary of Accounting Policies [Line Items]
Other income, net	700	400
PSNH | Equity in Earnings of Unconsolidated Affiliates
Summary of Accounting Policies [Line Items]
Other income, net	0	0
PSNH | Investment Income/(Loss)
Summary of Accounting Policies [Line Items]
Other income, net	(100)	200
PSNH | Interest Income
Summary of Accounting Policies [Line Items]
Other income, net	900	300
PSNH | Other
Summary of Accounting Policies [Line Items]
Other income, net	$ 0	$ 0

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Investments in Unconsolidated Affiliates (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 2,302,880	$ 2,176,080
Offshore Wind Business - North East Offshore
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	50.00%
Investments in unconsolidated affiliates	$ 2,159,200	1,947,100
Natural Gas Pipeline - Algonquin Gas Transmission, LLC
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	15.00%
Investments in unconsolidated affiliates	$ 117,500	118,800
Renewable Energy Investment Fund
Schedule of Equity Method Investments [Line Items]
Ownership interest (percent)	90.00%
Investments in unconsolidated affiliates	$ 0	84,100
Other
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 26,200	$ 26,100

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Other Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Schedule of Gross Tax Receipts [Line Items]
Gross receipts taxes	$ 55.0	$ 48.6
CL&P
Schedule of Gross Tax Receipts [Line Items]
Gross receipts taxes	$ 43.1	$ 37.8

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Non-cash Investing Activities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Schedule of Supplemental Cash Flow [Line Items]
Plant additions included in accounts payable	$ 400.8	$ 385.6
CL&P
Schedule of Supplemental Cash Flow [Line Items]
Plant additions included in accounts payable	101.9	102.1
NSTAR Electric
Schedule of Supplemental Cash Flow [Line Items]
Plant additions included in accounts payable	117.4	85.8
PSNH
Schedule of Supplemental Cash Flow [Line Items]
Plant additions included in accounts payable	$ 54.6	$ 49.5

XML

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Reconciliation of Cash Balances to Cash and Restricted Cash (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022	Mar. 31, 2022	Dec. 31, 2021
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and Cash Equivalents as reported on the Balance Sheets	$ 36,000	$ 374,600
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows	162,767	521,752	$ 164,589	$ 221,008
Special Deposits
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	89,000	102,200
Marketable Securities
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	17,900	25,400
Other Long-Term Assets
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	19,900	19,600
CL&P
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and Cash Equivalents as reported on the Balance Sheets	9,300	11,300
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows	18,409	20,327	30,584	74,788
CL&P | Special Deposits
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	8,900	8,800
CL&P | Marketable Securities
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	200	200
CL&P | Other Long-Term Assets
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	0	0
NSTAR Electric
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and Cash Equivalents as reported on the Balance Sheets	600	327,700
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows	18,355	345,293	18,144	18,179
NSTAR Electric | Special Deposits
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	17,800	17,500
NSTAR Electric | Marketable Securities
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	0	100
NSTAR Electric | Other Long-Term Assets
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	0	0
PSNH
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and Cash Equivalents as reported on the Balance Sheets	100	100
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows	23,012	36,812	$ 24,058	$ 35,126
PSNH | Special Deposits
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	19,500	33,100
PSNH | Marketable Securities
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	200	400
PSNH | Other Long-Term Assets
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 3,200	$ 3,200

XML

REGULATORY ACCOUNTING - Components of Regulatory Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 5,739,900	$ 5,578,300
Less:  Current Portion	1,332,028	1,335,491
Total Long-Term Regulatory Assets	4,407,875	4,242,794
Storm Costs, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	1,658,700	1,379,100
Regulatory Tracking Mechanisms
Regulatory Assets [Line Items]
Total Regulatory Assets	1,028,700	1,075,300
Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	910,300	921,700
Income Taxes, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	856,100	853,300
Securitized Stranded Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	424,900	435,700
Goodwill-related
Regulatory Assets [Line Items]
Total Regulatory Assets	276,700	281,000
Derivative Liabilities
Regulatory Assets [Line Items]
Total Regulatory Assets	168,800	181,800
Asset Retirement Obligations
Regulatory Assets [Line Items]
Total Regulatory Assets	129,200	127,900
Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	286,500	322,500
CL&P
Regulatory Assets [Line Items]
Total Regulatory Assets	1,996,500	1,907,800
Less:  Current Portion	356,468	314,089
Total Long-Term Regulatory Assets	1,639,960	1,593,693
CL&P | Storm Costs, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	889,200	799,300
CL&P | Regulatory Tracking Mechanisms
Regulatory Assets [Line Items]
Total Regulatory Assets	228,200	216,800
CL&P | Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	155,600	156,700
CL&P | Income Taxes, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	492,900	491,100
CL&P | Securitized Stranded Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
CL&P | Goodwill-related
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
CL&P | Derivative Liabilities
Regulatory Assets [Line Items]
Total Regulatory Assets	168,800	181,800
CL&P | Asset Retirement Obligations
Regulatory Assets [Line Items]
Total Regulatory Assets	36,500	35,900
CL&P | Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	25,300	26,200
NSTAR Electric
Regulatory Assets [Line Items]
Total Regulatory Assets	1,823,300	1,714,400
Less:  Current Portion	559,758	492,759
Total Long-Term Regulatory Assets	1,263,534	1,221,619
NSTAR Electric | Storm Costs, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	564,900	484,400
NSTAR Electric | Regulatory Tracking Mechanisms
Regulatory Assets [Line Items]
Total Regulatory Assets	432,400	391,500
NSTAR Electric | Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	294,400	299,500
NSTAR Electric | Income Taxes, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	118,100	115,600
NSTAR Electric | Securitized Stranded Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
NSTAR Electric | Goodwill-related
Regulatory Assets [Line Items]
Total Regulatory Assets	237,600	241,200
NSTAR Electric | Derivative Liabilities
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
NSTAR Electric | Asset Retirement Obligations
Regulatory Assets [Line Items]
Total Regulatory Assets	68,000	68,200
NSTAR Electric | Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	107,900	114,000
PSNH
Regulatory Assets [Line Items]
Total Regulatory Assets	838,500	696,200
Less:  Current Portion	140,912	102,240
Total Long-Term Regulatory Assets	697,568	593,974
PSNH | Storm Costs, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	204,600	95,400
PSNH | Regulatory Tracking Mechanisms
Regulatory Assets [Line Items]
Total Regulatory Assets	122,800	73,700
PSNH | Benefit Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	56,100	56,600
PSNH | Income Taxes, Net
Regulatory Assets [Line Items]
Total Regulatory Assets	13,100	16,000
PSNH | Securitized Stranded Costs
Regulatory Assets [Line Items]
Total Regulatory Assets	424,900	435,700
PSNH | Goodwill-related
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
PSNH | Derivative Liabilities
Regulatory Assets [Line Items]
Total Regulatory Assets	0	0
PSNH | Asset Retirement Obligations
Regulatory Assets [Line Items]
Total Regulatory Assets	4,500	4,400
PSNH | Other Regulatory Assets
Regulatory Assets [Line Items]
Total Regulatory Assets	$ 12,500	$ 14,400

XML

REGULATORY ACCOUNTING - Narrative (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Regulatory Assets [Line Items]
Amount of regulatory costs not yet approved	$ 223.6	$ 210.8
COVID-19
Regulatory Assets [Line Items]
Net incremental deferred costs	29.8	29.8
CL&P
Regulatory Assets [Line Items]
Amount of regulatory costs not yet approved	146.5	135.9
CL&P | COVID-19
Regulatory Assets [Line Items]
Net incremental deferred costs	11.8	11.8
NSTAR Electric
Regulatory Assets [Line Items]
Amount of regulatory costs not yet approved	19.7	19.8
NSTAR Electric | COVID-19
Regulatory Assets [Line Items]
Net incremental deferred costs	2.2	2.2
PSNH
Regulatory Assets [Line Items]
Amount of regulatory costs not yet approved	$ 1.1	$ 1.0

XML

REGULATORY ACCOUNTING - Components of Regulatory Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 4,624,900	$ 4,821,100
Less:  Current Portion	650,538	890,786
Total Long-Term Regulatory Liabilities	3,974,374	3,930,305
EDIT due to Tax Cuts and Jobs Act of 2017
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	2,601,800	2,619,300
Cost of Removal
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	705,400	670,600
Regulatory Tracking Mechanisms
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	653,600	890,800
Deferred Portion of Non-Service Income Components of Pension, SERP and PBOP
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	291,400	270,900
AFUDC - Transmission
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	103,800	98,200
Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	49,200	55,400
Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	219,700	215,900
CL&P
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	1,401,900	1,599,400
Less:  Current Portion	124,640	336,048
Total Long-Term Regulatory Liabilities	1,277,281	1,263,396
CL&P | EDIT due to Tax Cuts and Jobs Act of 2017
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	980,000	983,600
CL&P | Cost of Removal
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	144,200	130,800
CL&P | Regulatory Tracking Mechanisms
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	145,000	361,000
CL&P | Deferred Portion of Non-Service Income Components of Pension, SERP and PBOP
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	38,300	34,500
CL&P | AFUDC - Transmission
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	49,800	48,200
CL&P | Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	600	700
CL&P | Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	44,000	40,600
NSTAR Electric
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	1,932,600	1,921,300
Less:  Current Portion	375,047	373,221
Total Long-Term Regulatory Liabilities	1,557,614	1,548,081
NSTAR Electric | EDIT due to Tax Cuts and Jobs Act of 2017
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	933,900	944,300
NSTAR Electric | Cost of Removal
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	412,900	405,300
NSTAR Electric | Regulatory Tracking Mechanisms
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	341,600	336,100
NSTAR Electric | Deferred Portion of Non-Service Income Components of Pension, SERP and PBOP
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	148,500	139,700
NSTAR Electric | AFUDC - Transmission
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	54,000	50,000
NSTAR Electric | Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	27,100	31,400
NSTAR Electric | Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	14,600	14,500
PSNH
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	476,900	553,600
Less:  Current Portion	86,569	161,963
Total Long-Term Regulatory Liabilities	390,290	391,628
PSNH | EDIT due to Tax Cuts and Jobs Act of 2017
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	346,100	348,600
PSNH | Cost of Removal
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	20,200	14,700
PSNH | Regulatory Tracking Mechanisms
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	73,200	155,000
PSNH | Deferred Portion of Non-Service Income Components of Pension, SERP and PBOP
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	30,800	28,800
PSNH | AFUDC - Transmission
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	0	0
PSNH | Benefit Costs
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	0	0
PSNH | Other Regulatory Liabilities
Regulatory Liabilities [Line Items]
Total Regulatory Liabilities	$ 6,600	$ 6,500

XML

PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION - Summary of Property, Plant, and Equipment (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Public Utility, Property, Plant and Equipment [Line Items]
Distribution - Electric	$ 18,618,600	$ 18,326,200
Distribution - Natural Gas	7,562,800	7,443,800
Transmission - Electric	13,884,000	13,709,300
Distribution - Water	2,122,500	2,112,600
Solar	200,800	200,800
Utility	42,388,700	41,792,700
Other	1,791,700	1,738,100
Property, Plant and Equipment, Gross	44,180,400	43,530,800
Less:  Accumulated Depreciation
Utility	(9,317,700)	(9,167,400)
Other	(744,700)	(706,100)
Total Accumulated Depreciation	(10,062,400)	(9,873,500)
Property, Plant and Equipment, Net	34,118,000	33,657,300
Construction Work in Progress	2,626,900	2,455,500
Total Property, Plant and Equipment, Net	36,744,855	36,112,820
CL&P
Public Utility, Property, Plant and Equipment [Line Items]
Distribution - Electric	7,510,800	7,370,100
Transmission - Electric	6,235,200	6,165,100
Solar	0	0
Property, Plant and Equipment, Gross	13,746,000	13,535,200
Less:  Accumulated Depreciation
Total Accumulated Depreciation	(2,610,400)	(2,567,100)
Property, Plant and Equipment, Net	11,135,600	10,968,100
Construction Work in Progress	494,700	498,900
Total Property, Plant and Equipment, Net	11,630,278	11,467,024
NSTAR Electric
Public Utility, Property, Plant and Equipment [Line Items]
Distribution - Electric	8,516,700	8,410,000
Transmission - Electric	5,382,800	5,333,800
Solar	200,800	200,800
Property, Plant and Equipment, Gross	14,100,300	13,944,600
Less:  Accumulated Depreciation
Total Accumulated Depreciation	(3,429,300)	(3,381,200)
Property, Plant and Equipment, Net	10,671,000	10,563,400
Construction Work in Progress	1,148,000	1,063,600
Total Property, Plant and Equipment, Net	11,819,012	11,626,968
PSNH
Public Utility, Property, Plant and Equipment [Line Items]
Distribution - Electric	2,631,400	2,586,400
Transmission - Electric	2,267,600	2,212,000
Solar	0	0
Property, Plant and Equipment, Gross	4,899,000	4,798,400
Less:  Accumulated Depreciation
Total Accumulated Depreciation	(940,000)	(912,300)
Property, Plant and Equipment, Net	3,959,000	3,886,100
Construction Work in Progress	189,000	174,100
Total Property, Plant and Equipment, Net	$ 4,147,985	$ 4,060,224

XML

DERIVATIVE INSTRUMENTS - Gross Fair Values and Net Amounts of Contracts (Details) - CL&P - Level 3 - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Current Derivative Assets
Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]
Commodity Supply and Price Risk Management	$ 17.0	$ 16.3
Netting	(0.5)	(0.5)
Net Amount Recorded as a Derivative	16.5	15.8
Other Long-Term Assets
Derivative Assets (Liabilities), at Fair Value, Net, by Balance Sheet Classification [Abstract]
Commodity Supply and Price Risk Management	24.9	28.8
Netting	(0.8)	(0.9)
Net Amount Recorded as a Derivative	24.1	27.9
Current Derivative Liabilities
Current and Long-Term Derivative Liabilities
Commodity Supply and Price Risk Management	(85.1)	(81.6)
Netting	0.0	0.0
Net Amount Recorded as a Derivative	(85.1)	(81.6)
Long-Term Derivative Liabilities
Current and Long-Term Derivative Liabilities
Commodity Supply and Price Risk Management	(124.3)	(143.9)
Netting	0.0	0.0
Net Amount Recorded as a Derivative	$ (124.3)	$ (143.9)

XML

DERIVATIVE INSTRUMENTS - Narrative (Details) - MW	3 Months Ended
	Mar. 31, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of costs or benefits borne under capacity-related contracts by United Illuminated Company	20.00%
Amount of power to be purchased under capacity-related contract (in MW)	674	674
Level 3 | Minimum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of exit price premiums related to derivative contracts	2.30%
Level 3 | Maximum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of exit price premiums related to derivative contracts	6.60%
Level 3 | Weighted Average
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of exit price premiums related to derivative contracts	5.50%
CL&P
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Percentage of costs or benefits borne under capacity-related contracts	80.00%

XML

DERIVATIVE INSTRUMENTS - Summary of Level 3 Derivative Contracts and Significant Unobservable Inputs Used (Details) - CL&P - Forward Reserve Prices - Level 3 - $ / KWmo	Mar. 31, 2023	Dec. 31, 2022
Minimum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative measurement input	0.44	0.44
Maximum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative measurement input	0.50	0.50
Weighted Average
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative measurement input	0.47	0.47

XML

DERIVATIVE INSTRUMENTS - Changes in the Level 3 Category of Derivative Assets Measured at Fair Value on a Recurring Basis (Details) - CL&P - Level 3 - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Derivatives, Net [Rollforward]
Fair Value as of Beginning of Period	$ (181.8)	$ (249.2)
Net Realized/Unrealized (Losses)/Gains Included in Regulatory Assets	(1.9)	6.2
Settlements	14.9	13.6
Fair Value as of End of Period	$ (168.8)	$ (229.4)

XML

MARKETABLE SECURITIES - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Debt Securities, Available-for-sale [Line Items]
Available-for-sale equity securities	$ 19.6		$ 20.0
Unrealized (loss) gain recorded in other income	0.8	$ (4.4)
Losses recorded on securities intended to be sold	3.2	1.5
Unrealized Gains/(Losses) on Marketable Securities
Debt Securities, Available-for-sale [Line Items]
Losses recorded on securities intended to be sold	1.2	$ 0.0
CYAPC and YAEC
Debt Securities, Available-for-sale [Line Items]
Available-for-sale equity securities	170.9		170.1
Marketable securities held in nuclear decommissioning trust	$ 161.2		$ 163.2

XML

MARKETABLE SECURITIES - Summary of Available-for-Sale Debt Securities (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Investments, Debt and Equity Securities [Abstract]
Amortized Cost	$ 196.5	$ 201.6
Pre-Tax Unrealized Gains	0.2	0.1
Pre-Tax Unrealized Losses	(14.8)	(16.2)
Fair Value	$ 181.9	$ 185.5

XML

MARKETABLE SECURITIES - Contractual Maturities of Available-for-Sale Debt Securities (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Amortized Cost
Less than one year	$ 39.8
One to five years	42.5
Six to ten years	35.6
Greater than ten years	78.6
Amortized Cost	196.5	$ 201.6
Fair Value
Less than one year	38.9
One to five years	41.1
Six to ten years	32.8
Greater than ten years	69.1
Fair Value	$ 181.9	$ 185.5

XML

MARKETABLE SECURITIES - Marketable Securities Recorded at Fair Value on a Recurring Basis by Level (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	$ 372.4	$ 375.6
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	208.4	215.5
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	164.0	160.1
Mutual Funds and Equities | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	190.5	190.1
Money Market Funds | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	17.9	25.4
U.S. Government Issued Debt Securities (Agency and Treasury) | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	91.5	82.3
Corporate Debt Securities | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	44.2	46.1
Asset-Backed Debt Securities | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	8.5	8.6
Municipal Bonds | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	9.2	12.7
Other Fixed Income Securities | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Marketable securities	$ 10.6	$ 10.4

XML

SHORT-TERM AND LONG-TERM DEBT - Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2023	Dec. 31, 2022
CL&P
Line of Credit Facility [Line Items]
Notes payable to Eversource parent	$ 318,000,000
PSNH
Line of Credit Facility [Line Items]
Notes payable to Eversource parent	121,100,000	$ 173,300,000
Line of Credit | CL&P
Line of Credit Facility [Line Items]
Maximum borrowing capacity	450,000,000
Amount outstanding under line of credit	0
Line of Credit | PSNH
Line of Credit Facility [Line Items]
Maximum borrowing capacity	300,000,000
Amount outstanding under line of credit	0
Commercial Paper | NSTAR Electric
Line of Credit Facility [Line Items]
Maximum borrowing capacity	650,000,000
Line of Credit
Line of Credit Facility [Line Items]
Amount outstanding under line of credit	0	$ 0
Line of Credit | NSTAR Electric
Line of Credit Facility [Line Items]
Maximum borrowing capacity	650,000,000
Eversource Parent | Commercial Paper
Line of Credit Facility [Line Items]
Maximum borrowing capacity	2,000,000,000
Eversource Parent | Line of Credit
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 2,000,000,000
Debt instrument term	5 years
NSTAR Electric | Line of Credit | NSTAR Electric
Line of Credit Facility [Line Items]
Debt instrument term	5 years

XML

SHORT-TERM AND LONG-TERM DEBT - Borrowings Outstanding and Available under the Commercial Paper Programs (Details) - Commercial Paper - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Borrowings outstanding	$ 1,048.0	$ 1,442.2
Available borrowing capacity	$ 952.0	$ 557.8
Weighted-average interest rate (in percent)	5.22%	4.63%
NSTAR Electric
Debt Instrument [Line Items]
Borrowings outstanding	$ 147.5	$ 0.0
Available borrowing capacity	$ 502.5	$ 650.0
Weighted-average interest rate (in percent)	4.77%	0.00%

XML

SHORT-TERM AND LONG-TERM DEBT - Summary of Long-Term Debt Issuance and Repayments (Details) - USD ($) $ in Thousands	1 Months Ended			3 Months Ended
	May 31, 2023	Mar. 31, 2023	Jan. 31, 2023	Mar. 31, 2023	Mar. 31, 2022
Debt Instrument [Line Items]
Retirement of Long-Term Debt				$ (400,000)	$ (770,000)
CL&P
Debt Instrument [Line Items]
Retirement of Long-Term Debt				$ (400,000)	$ 0
CL&P | First Mortgage | CL&P 2023 Series A First Mortgage Bonds
Debt Instrument [Line Items]
Interest rate, stated percentage			5.25%
Issuances			$ 500,000
CL&P | First Mortgage | CL&P 2013 Series A First Mortgage Bonds
Debt Instrument [Line Items]
Interest rate, stated percentage			2.50%
Retirement of Long-Term Debt			$ (400,000)
PSNH | First Mortgage | PSNH Series W First Mortgage Bonds
Debt Instrument [Line Items]
Interest rate, stated percentage			5.15%
Issuances			$ 300,000
Eversource Parent | Senior Notes | Eversource Parent Series Z Senior Notes
Debt Instrument [Line Items]
Interest rate, stated percentage		5.45%		5.45%
Issuances		$ 750,000
Eversource Parent | Senior Notes | Eversource Parent Series F Senior Notes | Forecast
Debt Instrument [Line Items]
Interest rate, stated percentage	2.80%
Eversource Parent | Senior Notes | Eversource Parent Series F Senior Notes | Subsequent Event | Forecast
Debt Instrument [Line Items]
Retirement of Long-Term Debt	$ (450,000)

XML

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES - Narrative (Details) - PSNH - Rate Reduction Bonds $ in Millions	May 31, 2018 USD ($)
Debt Instrument [Line Items]
Amount of securitized rate reduction bonds issued	$ 635.7
Weighted average interest rate	3.66%

XML

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES - Summary of the Impact of Funding on the Balance Sheets (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	$ 5,739,900	$ 5,578,300
Regulatory Liabilities	3,974,374	3,930,305
Accrued Interest (included in Other Current Liabilities)	1,078,421	989,053
Rate Reduction Bonds - Current Portion	43,210	43,210
Rate Reduction Bonds - Long-Term Portion	388,887	410,492
Securitized Stranded Costs
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	424,900	435,700
Other Regulatory Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	286,500	322,500
Current Derivative Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	89,000	102,200
Other Long-Term Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	19,900	19,600
PSNH
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	838,500	696,200
Regulatory Liabilities	390,290	391,628
Accrued Interest (included in Other Current Liabilities)	62,784	59,616
Rate Reduction Bonds - Current Portion	43,210	43,210
Rate Reduction Bonds - Long-Term Portion	388,887	410,492
PSNH | VIE
Condensed Balance Sheet Statements, Captions [Line Items]
Rate Reduction Bonds - Current Portion	43,200	43,200
Rate Reduction Bonds - Long-Term Portion	388,900	410,500
PSNH | Securitized Stranded Costs
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	424,900	435,700
PSNH | Securitized Stranded Costs | VIE
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	424,900	435,700
PSNH | Other Regulatory Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Securitized Stranded Cost (included in Regulatory Assets)	12,500	14,400
PSNH | Other Regulatory Assets | VIE
Condensed Balance Sheet Statements, Captions [Line Items]
Regulatory Liabilities	8,800	6,000
Accrued Interest (included in Other Current Liabilities)	2,700	6,900
PSNH | Current Derivative Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	19,500	33,100
PSNH | Current Derivative Assets | VIE
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	18,700	32,400
PSNH | Other Long-Term Assets
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	3,200	3,200
PSNH | Other Long-Term Assets | VIE
Condensed Balance Sheet Statements, Captions [Line Items]
Restricted Cash	$ 3,200	$ 3,200

XML

RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES - Summary of the Impact of Funding on the Income Statements (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Condensed Income Statements, Captions [Line Items]
Interest Expense on RRB Principal (included in Interest Expense)	$ 194,543	$ 153,245
PSNH
Condensed Income Statements, Captions [Line Items]
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	5,317	(26,834)
Interest Expense on RRB Principal (included in Interest Expense)	17,542	13,645
PSNH | VIE | Rate Reduction Bonds
Condensed Income Statements, Captions [Line Items]
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	10,800	10,800
Interest Expense on RRB Principal (included in Interest Expense)	$ 4,100	$ 4,400

XML

PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION - Components of Net Periodic Benefit Expense/(Income) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Pension and SERP
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	$ 11.0	$ 17.7
Interest Cost	63.7	38.6
Expected Return on Plan Assets	(115.9)	(131.7)
Actuarial Losses, net	12.5	30.7
Prior Service Cost/(Credit)	0.3	0.4
Total Net Periodic Benefit Plan Income	(28.4)	(44.3)
PBOP
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	1.8	2.8
Interest Cost	8.5	5.0
Expected Return on Plan Assets	(19.1)	(22.4)
Actuarial Losses, net	0.0	0.0
Prior Service Cost/(Credit)	(5.4)	(5.4)
Total Net Periodic Benefit Plan Income	(14.2)	(20.0)
CL&P | Pension and SERP
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	3.0	4.5
Interest Cost	12.6	7.8
Expected Return on Plan Assets	(23.4)	(26.6)
Actuarial Losses, net	0.8	4.2
Prior Service Cost/(Credit)	0.0	0.0
Total Net Periodic Benefit Plan Income	(7.0)	(10.1)
Intercompany Income Allocations	(2.0)	(3.8)
CL&P | PBOP
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	0.3	0.5
Interest Cost	1.6	0.9
Expected Return on Plan Assets	(2.4)	(2.8)
Actuarial Losses, net	0.0	0.0
Prior Service Cost/(Credit)	0.3	0.2
Total Net Periodic Benefit Plan Income	(0.2)	(1.2)
Intercompany Income Allocations	(0.5)	(0.9)
NSTAR Electric | Pension and SERP
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	2.1	3.6
Interest Cost	13.5	8.1
Expected Return on Plan Assets	(28.4)	(32.0)
Actuarial Losses, net	4.9	8.5
Prior Service Cost/(Credit)	0.1	0.1
Total Net Periodic Benefit Plan Income	(7.8)	(11.7)
Intercompany Income Allocations	(1.7)	(2.9)
NSTAR Electric | PBOP
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	0.3	0.5
Interest Cost	2.3	1.3
Expected Return on Plan Assets	(9.2)	(10.6)
Actuarial Losses, net	0.0	0.0
Prior Service Cost/(Credit)	(4.2)	(4.3)
Total Net Periodic Benefit Plan Income	(10.8)	(13.1)
Intercompany Income Allocations	(0.6)	(0.9)
PSNH | Pension and SERP
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	1.1	1.8
Interest Cost	6.8	4.2
Expected Return on Plan Assets	(12.3)	(14.1)
Actuarial Losses, net	0.4	2.2
Prior Service Cost/(Credit)	0.0	0.0
Total Net Periodic Benefit Plan Income	(4.0)	(5.9)
Intercompany Income Allocations	(0.5)	(0.8)
PSNH | PBOP
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	0.2	0.2
Interest Cost	0.9	0.5
Expected Return on Plan Assets	(1.4)	(1.6)
Actuarial Losses, net	0.0	0.0
Prior Service Cost/(Credit)	0.1	0.1
Total Net Periodic Benefit Plan Income	(0.2)	(0.8)
Intercompany Income Allocations	$ (0.2)	$ (0.3)

XML

COMMITMENTS AND CONTINGENCIES - Environmental Sites and Related Reserves (Details) $ in Millions	3 Months Ended	9 Months Ended
	Mar. 31, 2023 USD ($) site	Sep. 30, 2022 site	Dec. 31, 2022 USD ($)
Site Contingency [Line Items]
Number of Sites | site	59	59
Reserve | $	$ 121.2		$ 122.6
CL&P
Site Contingency [Line Items]
Number of Sites | site	13	13
Reserve | $	$ 13.6		13.9
NSTAR Electric
Site Contingency [Line Items]
Number of Sites | site	10	10
Reserve | $	$ 3.4		3.4
PSNH
Site Contingency [Line Items]
Number of Sites | site	8	8
Reserve | $	$ 6.1		$ 6.1

XML

COMMITMENTS AND CONTINGENCIES - Environmental Matters Narrative (Details) - USD ($) $ in Millions	Mar. 31, 2023	Dec. 31, 2022
Site Contingency [Line Items]
Reserve balance	$ 121.2	$ 122.6
MGP Sites
Site Contingency [Line Items]
Reserve balance	$ 111.7	$ 112.6

XML

COMMITMENTS AND CONTINGENCIES - Guarantees and Obligations Narrative (Details) - USD ($) $ in Millions	Jun. 30, 2023	Mar. 31, 2023	Dec. 31, 2022
Guarantor Obligations [Line Items]
Fair value of guarantees		$ 5.4	$ 4.2
Forecast | Sunrise Wind LLC | Subsequent Event
Guarantor Obligations [Line Items]
Additional guaranty	$ 86.1

XML

COMMITMENTS AND CONTINGENCIES - Guarantees and Indemnifications (Details) $ in Millions	Mar. 31, 2023 USD ($)	Jan. 31, 2022 USD ($) letterOfCredit	Sep. 16, 2020 USD ($)
Guarantor Obligations [Line Items]
Number of letters of credit | letterOfCredit		2
Letters of Credit | Eversource Investment LLC
Guarantor Obligations [Line Items]
Maximum borrowing capacity			$ 25.0
North East Offshore LLC
Guarantor Obligations [Line Items]
Ownership interest (percent)	50.00%
Sunrise Wind LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 838.4
Ownership interest (percent)	50.00%
Revolution Wind, LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 547.1
Ownership interest (percent)	50.00%
South Fork Wind, LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 7.1
Ownership interest (percent)	50.00%
South Fork Wind, LLC | Letters of Credit
Guarantor Obligations [Line Items]
Amount outstanding under line of credit		$ 4.3
Eversource Investment LLC | North East Offshore LLC
Guarantor Obligations [Line Items]
Ownership interest (percent)	50.00%
Construction-related purchase agreements with third-party contractors | South Fork Wind, LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 207.7
Ownership interest (percent)	50.00%
Construction-related purchase agreements with third-party contractors | North East Offshore LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 726.2
Construction-related purchase agreements with third-party contractors | Sunrise Wind LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	668.6
Construction-related purchase agreements with third-party contractors | Revolution Wind, LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	409.7
Construction-related purchase agreements with third-party contractors | South Fork Wind, LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	126.2
Funding and indemnification obligations of North East Offshore LLC | Eversource Investment LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	68.9
Funding and indemnification obligations of North East Offshore LLC | Eversource Investment LLC | North East Offshore LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	910.0
Power Purchase Agreement | South Fork Wind, LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	7.1
OREC capacity production | Sunrise Wind LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 15.4
Ownership interest (percent)	50.00%
OREC capacity production | Sunrise Wind LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 11.0
Real estate purchase | Bay State Wind LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	2.5
Transmission interconnection | South Fork Wind, LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	1.2
Letters of Credit | Eversource Investment LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	4.3
Surety bonds | Various
Guarantor Obligations [Line Items]
Maximum exposure (up to)	37.2
Lease payments for real estate | Eversource Service
Guarantor Obligations [Line Items]
Maximum exposure (up to)	0.4
Performance guarantee | North East Offshore LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 1,300.0
Percent of obligations guaranteed	50.00%
Payment guarantee | North East Offshore LLC
Guarantor Obligations [Line Items]
Maximum exposure (up to)	$ 62.5
Percent of obligations guaranteed	50.00%

XML

COMMITMENTS AND CONTINGENCIES - Spent Nuclear Fuel Obligations - Yankee Companies (Details) - Yankee Companies - USD ($) $ in Millions	Jun. 08, 2022	Mar. 25, 2021
Loss Contingencies [Line Items]
Damages sought	$ 33.1
CYAPC, YAEC, and MYAPC
Loss Contingencies [Line Items]
Damages sought		$ 120.4

XML

COMMITMENTS AND CONTINGENCIES - FERC ROE Complaints (Details) $ in Millions			3 Months Ended	36 Months Ended
	Apr. 29, 2016 complaint	Oct. 16, 2014	Mar. 31, 2023 USD ($) period	Oct. 15, 2014	Dec. 31, 2022 USD ($)	Dec. 23, 2019 complaint	Nov. 21, 2019 complaint	Oct. 16, 2018 complaint	Jul. 31, 2014 complaint
Loss Contingencies [Line Items]
Percentage of base ROE reasonably justified			10.41%
Percentage of incentive cap on total ROE			13.08%
FERC ROE Complaints
Loss Contingencies [Line Items]
Number of complaints filed | complaint	4					4	2	4
Period of complaint			15 months
Basis point change			0.10%
Estimate of possible loss for each 10 basis point change to base ROE			$ 3.0
Number of complain periods | period			4
FERC ROE First, Second and Third Complaints
Loss Contingencies [Line Items]
Number of complaints filed | complaint									3
Base ROE subsequently authorized			11.14%
FERC ROE First, Second and Third Complaints | Minimum
Loss Contingencies [Line Items]
Percentage of maximum ROE for any incentive project				11.14%
FERC ROE First, Second and Third Complaints | Maximum
Loss Contingencies [Line Items]
Percentage of maximum ROE for any incentive project				13.10%
FERC ROE Fourth Complaint
Loss Contingencies [Line Items]
Base ROE percentage of complaint period	10.57%
Maximum percentage cap of ROE for incentive projects	11.74%
FERC ROE First Complaint
Loss Contingencies [Line Items]
Base ROE subsequently authorized		10.57%
Percentage of maximum ROE for any incentive project		11.74%
Amounts associated with first complaint refunded			$ 38.9
FERC ROE First Complaint | CL&P
Loss Contingencies [Line Items]
Amounts associated with first complaint refunded			22.4
FERC ROE First Complaint | NSTAR Electric
Loss Contingencies [Line Items]
Amounts associated with first complaint refunded			13.7
FERC ROE First Complaint | PSNH
Loss Contingencies [Line Items]
Amounts associated with first complaint refunded			$ 2.8
FERC ROE Second Complaint
Loss Contingencies [Line Items]
Base ROE percentage of complaint period			10.57%
Percentage of maximum ROE for any incentive project			11.74%
Loss contingency, estimate of possible earnings impact			$ 39.1		$ 39.1
FERC ROE Second Complaint | CL&P
Loss Contingencies [Line Items]
Loss contingency, estimate of possible earnings impact			21.4		21.4
FERC ROE Second Complaint | NSTAR Electric
Loss Contingencies [Line Items]
Loss contingency, estimate of possible earnings impact			14.6		14.6
FERC ROE Second Complaint | PSNH
Loss Contingencies [Line Items]
Loss contingency, estimate of possible earnings impact			$ 3.1		$ 3.1

XML

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Thousands	Mar. 31, 2023	Dec. 31, 2022
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	$ 155,570	$ 155,570
Rate Reduction Bonds	388,887	410,492
Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	155,600	155,600
Long-Term Debt	22,178,000	21,044,100
Rate Reduction Bonds	432,100	453,700
Fair Value | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	137,100	136,700
Long-Term Debt	20,650,500	18,891,300
Rate Reduction Bonds	417,300	424,700
CL&P
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	116,200	116,200
CL&P | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	116,200	116,200
Long-Term Debt	4,310,200	4,216,500
Rate Reduction Bonds	0	0
CL&P | Fair Value | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	100,800	99,200
Long-Term Debt	4,096,900	3,828,300
Rate Reduction Bonds	0	0
NSTAR Electric
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	43,000	43,000
NSTAR Electric | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	43,000	43,000
Long-Term Debt	4,426,000	4,425,100
Rate Reduction Bonds	0	0
NSTAR Electric | Fair Value | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	36,300	37,500
Long-Term Debt	4,217,400	4,091,800
Rate Reduction Bonds	0	0
PSNH
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Rate Reduction Bonds	388,887	410,492
PSNH | Carrying Amount
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	0	0
Long-Term Debt	1,459,400	1,164,600
Rate Reduction Bonds	432,100	453,700
PSNH | Fair Value | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Preferred Stock Not Subject to Mandatory Redemption	0	0
Long-Term Debt	1,331,700	970,500
Rate Reduction Bonds	$ 417,300	$ 424,700

XML

ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
AOCI Attributable to Parent [Roll Forward]
OCI Before Reclassifications	$ 0	$ (800)
Amounts Reclassified from AOCI	3,200	1,500
Other Comprehensive Income (Loss), Net of Tax	3,230	704
Accumulated Other Comprehensive Loss
AOCI Attributable to Parent [Roll Forward]
Beginning balance	(39,400)	(42,300)
Other Comprehensive Income (Loss), Net of Tax	3,230	704
Ending balance	(36,200)	(41,600)
Qualified Cash Flow Hedging Instruments
AOCI Attributable to Parent [Roll Forward]
Beginning balance	(400)	(400)
OCI Before Reclassifications	0	0
Amounts Reclassified from AOCI	0	0
Other Comprehensive Income (Loss), Net of Tax	0	0
Ending balance	(400)	(400)
Unrealized Gains/(Losses) on Marketable Securities
AOCI Attributable to Parent [Roll Forward]
Beginning balance	(1,200)	400
OCI Before Reclassifications	0	(800)
Amounts Reclassified from AOCI	1,200	0
Other Comprehensive Income (Loss), Net of Tax	1,200	(800)
Ending balance	0	(400)
Defined Benefit Plans
AOCI Attributable to Parent [Roll Forward]
Beginning balance	(37,800)	(42,300)
OCI Before Reclassifications	0	0
Amounts Reclassified from AOCI	2,000	1,500
Other Comprehensive Income (Loss), Net of Tax	2,000	1,500
Ending balance	$ (35,800)	$ (40,800)

XML

COMMON SHARES - Common Shares Authorized and Issued (Details) - $ / shares	Mar. 31, 2023	Dec. 31, 2022
Class of Stock [Line Items]
Par value (in dollars per share)	$ 5	$ 5
Authorized (in shares)	380,000,000	380,000,000
Issued (in shares)	359,984,073	359,984,073
CL&P
Class of Stock [Line Items]
Par value (in dollars per share)	$ 10	$ 10
Authorized (in shares)	24,500,000	24,500,000
Issued (in shares)	6,035,205	6,035,205
NSTAR Electric
Class of Stock [Line Items]
Par value (in dollars per share)	$ 1	$ 1
Authorized (in shares)	100,000,000	100,000,000
Issued (in shares)	200	200
PSNH
Class of Stock [Line Items]
Par value (in dollars per share)	$ 1	$ 1
Authorized (in shares)	100,000,000	100,000,000
Issued (in shares)	301	301

XML

COMMON SHARES - Narrative (Details) - shares	May 03, 2023	May 02, 2023	Mar. 31, 2023	Dec. 31, 2022
Class of Stock [Line Items]
Treasury stock (in shares)			11,175,991	11,540,218
Common stock outstanding (in shares)			348,808,082	348,443,855
Authorized (in shares)			380,000,000	380,000,000
Subsequent Event
Class of Stock [Line Items]
Authorized (in shares)	410,000,000	380,000,000

XML

COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Equity [Abstract]
Dividends on preferred stock	$ 1,880	$ 1,880
Noncontrolling interest attributed to preferred stock of subsidiaries	$ 155,570		$ 155,570

XML

EARNINGS PER SHARE - Narrative (Details) - shares	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Earnings Per Share [Abstract]
Antidilutive share awards excluded from the EPS computation (in shares)	0	0

XML

EARNINGS PER SHARE - Components of Basic and Diluted EPS (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022
Earnings Per Share [Abstract]
Net Income Attributable to Common Shareholders	$ 491,159	$ 443,446
Net Income Attributable to Common Shareholders	$ 491,200	$ 443,400
Weighted Average Common Shares Outstanding:
Basic (in shares)	349,217,147	345,156,346
Dilutive effect (in shares)	394,866	504,787
Diluted (in shares)	349,612,013	345,661,133
Basic EPS (in dollars per share)	$ 1.41	$ 1.28
Diluted EPS (in dollars per share)	$ 1.41	$ 1.28

XML

REVENUES (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2021	Sep. 01, 2021
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	$ 3,751,800	$ 3,452,000
Alternative Revenue Programs	36,900	15,800
Other Revenues	6,900	3,500
Operating Revenues	3,795,643	3,471,310
Customer Credits at CL&P related to PURA Settlement Agreement and Storm Performance Penalty	0	(58,412)
CL&P
Disaggregation of Revenue [Line Items]
Operating Revenues	1,338,905	1,285,831
Customer Credits at CL&P related to PURA Settlement Agreement and Storm Performance Penalty	0	(58,412)
CL&P | Unfavorable Regulatory Action
Disaggregation of Revenue [Line Items]
Loss contingency, estimate of possible earnings impact, non-compliance with performance standards				$ 28,400
CL&P | Unfavorable Regulatory Action | Sales
Disaggregation of Revenue [Line Items]
Customer Credits at CL&P related to PURA Settlement Agreement and Storm Performance Penalty			$ 65,000
NSTAR Electric
Disaggregation of Revenue [Line Items]
Operating Revenues	956,283	863,176
PSNH
Disaggregation of Revenue [Line Items]
Operating Revenues	420,155	339,427
Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	3,347,100	2,857,900
Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	2,069,500	1,771,200
Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	1,122,900	932,400
Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	154,700	154,300
Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	109,700	105,900
Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	267,200	399,800
Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	27,800	30,400
Amortization of/(Reserve for) Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers		58,000
Operating Segments | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	1,451,800	1,430,100
Alternative Revenue Programs	24,600	1,300
Other Revenues	2,200	100
Operating Segments | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	1,104,400	1,004,700
Alternative Revenue Programs	(9,500)	(8,200)
Other Revenues	2,500	2,000
Operating Segments | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	461,100	395,100
Alternative Revenue Programs	9,600	(3,300)
Other Revenues	1,000	900
Operating Segments | Total Retail Tariff Sales Revenues | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	1,091,400	874,800
Operating Segments | Total Retail Tariff Sales Revenues | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	884,700	770,000
Operating Segments | Total Retail Tariff Sales Revenues | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	365,200	292,900
Operating Segments | Residential | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	762,200	599,100
Operating Segments | Residential | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	467,800	404,600
Operating Segments | Residential | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	234,000	182,500
Operating Segments | Commercial | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	295,300	242,200
Operating Segments | Commercial | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	384,300	331,300
Operating Segments | Commercial | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	108,600	88,400
Operating Segments | Industrial | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	33,900	33,500
Operating Segments | Industrial | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	32,600	34,100
Operating Segments | Industrial | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	22,600	22,000
Operating Segments | Wholesale Transmission Revenues | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	195,800	209,100
Operating Segments | Wholesale Transmission Revenues | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	167,800	165,200
Operating Segments | Wholesale Transmission Revenues | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	71,400	71,900
Operating Segments | Wholesale Market Sales Revenues | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	154,600	279,900
Operating Segments | Wholesale Market Sales Revenues | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	41,100	57,900
Operating Segments | Wholesale Market Sales Revenues | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	21,600	27,700
Operating Segments | Other Revenues from Contracts with Customers | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	9,300	7,900
Operating Segments | Other Revenues from Contracts with Customers | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	10,800	11,600
Operating Segments | Other Revenues from Contracts with Customers | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	2,900	2,600
Operating Segments | Amortization of/(Reserve for) Revenues Subject to Refund | CL&P
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	700	58,400
Operating Segments | Amortization of/(Reserve for) Revenues Subject to Refund | NSTAR Electric
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Operating Segments | Amortization of/(Reserve for) Revenues Subject to Refund | PSNH
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Operating Segments | Amortization Of (Reserves For) Revenues Subject To Refund | CL&P | Unfavorable Regulatory Action
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers			$ 93,400
Other
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	413,800	383,500
Alternative Revenue Programs	0	0
Other Revenues	0	0
Operating Revenues	413,800	383,500
Other | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Other | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Other | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Other | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Other | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	24,400
Other | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Other | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	413,800	359,100
Other | Amortization of/(Reserve for) Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers		0
Eliminations
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	(744,000)	(723,400)
Alternative Revenue Programs	(16,900)	13,600
Other Revenues	0	0
Operating Revenues	(760,900)	(709,800)
Eliminations | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	(6,100)	(5,600)
Eliminations | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Eliminations | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	(1,000)	(1,100)
Eliminations | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	(5,100)	(4,500)
Eliminations | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	(325,300)	(364,700)
Eliminations | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Eliminations | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	(412,600)	(353,100)
Eliminations | Amortization of/(Reserve for) Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers		0
Consolidations Eliminations | CL&P
Disaggregation of Revenue [Line Items]
Operating Revenues	(139,700)	(145,700)
Consolidations Eliminations | NSTAR Electric
Disaggregation of Revenue [Line Items]
Operating Revenues	(141,100)	(135,300)
Consolidations Eliminations | PSNH
Disaggregation of Revenue [Line Items]
Operating Revenues	(51,500)	(53,300)
Electric Distribution | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	2,577,100	2,378,700
Alternative Revenue Programs	6,000	4,800
Other Revenues	5,500	2,800
Operating Revenues	2,588,600	2,386,300
Electric Distribution | Operating Segments | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	2,341,500	1,937,100
Electric Distribution | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	1,464,000	1,186,200
Electric Distribution | Operating Segments | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	788,400	661,300
Electric Distribution | Operating Segments | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	89,100	89,600
Electric Distribution | Operating Segments | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Electric Distribution | Operating Segments | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	217,300	365,500
Electric Distribution | Operating Segments | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	18,300	17,700
Electric Distribution | Operating Segments | Amortization of/(Reserve for) Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers		58,400
Natural Gas Distribution | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	1,016,800	917,000
Alternative Revenue Programs	27,400	10,200
Other Revenues	1,000	400
Operating Revenues	1,045,200	927,600
Natural Gas Distribution | Operating Segments | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	966,200	882,500
Natural Gas Distribution | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	576,600	556,800
Natural Gas Distribution | Operating Segments | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	320,000	257,600
Natural Gas Distribution | Operating Segments | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	69,600	68,100
Natural Gas Distribution | Operating Segments | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Natural Gas Distribution | Operating Segments | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	49,100	33,500
Natural Gas Distribution | Operating Segments | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	1,500	1,000
Natural Gas Distribution | Operating Segments | Amortization of/(Reserve for) Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers		0
Electric Transmission | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	439,700	450,000
Alternative Revenue Programs	18,700	(15,000)
Other Revenues	200	200
Operating Revenues	458,600	435,200
Electric Transmission | Operating Segments | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Electric Transmission | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Electric Transmission | Operating Segments | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Electric Transmission | Operating Segments | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Electric Transmission | Operating Segments | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	435,000	446,200
Electric Transmission | Operating Segments | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Electric Transmission | Operating Segments | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	4,700	3,800
Electric Transmission | Operating Segments | Amortization of/(Reserve for) Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers		0
Water Distribution | Operating Segments
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	48,400	46,200
Alternative Revenue Programs	1,700	2,200
Other Revenues	200	100
Operating Revenues	50,300	48,500
Water Distribution | Operating Segments | Total Retail Tariff Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	45,500	43,900
Water Distribution | Operating Segments | Residential
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	28,900	28,200
Water Distribution | Operating Segments | Commercial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	15,500	14,600
Water Distribution | Operating Segments | Industrial
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	1,100	1,100
Water Distribution | Operating Segments | Wholesale Transmission Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	0	0
Water Distribution | Operating Segments | Wholesale Market Sales Revenues
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	800	800
Water Distribution | Operating Segments | Other Revenues from Contracts with Customers
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers	$ 2,100	1,900
Water Distribution | Operating Segments | Amortization of/(Reserve for) Revenues Subject to Refund
Disaggregation of Revenue [Line Items]
Revenues from Contracts with Customers		$ (400)

XML

SEGMENT INFORMATION - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2023 USD ($) reportableSegment
CL&P
Segment Reporting Information [Line Items]
Number of reportable segments	1
NSTAR Electric
Segment Reporting Information [Line Items]
Number of reportable segments	1
PSNH
Segment Reporting Information [Line Items]
Number of reportable segments	1
Affiliated Entity
Segment Reporting Information [Line Items]
Amount of natural gas transmission purchased | $	$ 77.7

XML

SEGMENT INFORMATION - Summary of Segment Information and Segmented Total Assets (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2023	Mar. 31, 2022	Dec. 31, 2022
Segment Reporting Information [Line Items]
Operating Revenues	$ 3,795,643	$ 3,471,310
Depreciation and Amortization	(236,900)	(526,300)
Other Operating Expenses	(2,809,100)	(2,281,900)
Operating Income/(Loss)	749,573	663,055
Interest Expense	(194,543)	(153,245)
Other Income, Net	88,981	71,561
Net Income/(Loss) Attributable to Common Shareholders	491,159	443,446
Cash Flows Used for Investments in Plant	977,144	764,594
Assets	54,105,167		$ 53,230,900
Other
Segment Reporting Information [Line Items]
Operating Revenues	413,800	383,500
Depreciation and Amortization	(36,800)	(30,200)
Other Operating Expenses	(339,600)	(331,400)
Operating Income/(Loss)	37,400	21,900
Interest Expense	(85,100)	(46,800)
Other Income, Net	565,800	495,900
Net Income/(Loss) Attributable to Common Shareholders	516,900	468,700
Cash Flows Used for Investments in Plant	65,200	62,100
Assets	27,186,400		26,365,200
Eliminations
Segment Reporting Information [Line Items]
Operating Revenues	(760,900)	(709,800)
Depreciation and Amortization	2,100	1,600
Other Operating Expenses	759,300	708,800
Operating Income/(Loss)	500	600
Interest Expense	32,000	10,100
Other Income, Net	(550,600)	(493,100)
Net Income/(Loss) Attributable to Common Shareholders	(518,100)	(482,400)
Cash Flows Used for Investments in Plant	0	0
Assets	(25,514,600)		(24,737,500)
Electric Distribution | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues	2,588,600	2,386,300
Depreciation and Amortization	(22,000)	(351,600)
Other Operating Expenses	(2,342,300)	(1,845,600)
Operating Income/(Loss)	224,300	189,100
Interest Expense	(69,300)	(59,400)
Other Income, Net	54,300	47,600
Net Income/(Loss) Attributable to Common Shareholders	165,500	140,900
Cash Flows Used for Investments in Plant	371,900	280,500
Assets	27,978,800		27,365,000
Natural Gas Distribution | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues	1,045,200	927,600
Depreciation and Amortization	(77,000)	(51,900)
Other Operating Expenses	(730,400)	(657,300)
Operating Income/(Loss)	237,800	218,400
Interest Expense	(21,200)	(15,800)
Other Income, Net	9,000	10,100
Net Income/(Loss) Attributable to Common Shareholders	170,300	164,000
Cash Flows Used for Investments in Plant	165,500	127,300
Assets	8,127,800		8,084,900
Electric Transmission | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues	458,600	435,200
Depreciation and Amortization	(89,900)	(81,900)
Other Operating Expenses	(128,200)	(129,300)
Operating Income/(Loss)	240,500	224,000
Interest Expense	(41,500)	(33,200)
Other Income, Net	9,400	8,900
Net Income/(Loss) Attributable to Common Shareholders	155,100	148,500
Cash Flows Used for Investments in Plant	336,600	266,900
Assets	13,522,600		13,369,500
Water Distribution | Operating Segments
Segment Reporting Information [Line Items]
Operating Revenues	50,300	48,500
Depreciation and Amortization	(13,300)	(12,300)
Other Operating Expenses	(27,900)	(27,100)
Operating Income/(Loss)	9,100	9,100
Interest Expense	(9,400)	(8,200)
Other Income, Net	1,100	2,200
Net Income/(Loss) Attributable to Common Shareholders	1,500	3,700
Cash Flows Used for Investments in Plant	37,900	$ 27,800
Assets	$ 2,804,200		$ 2,783,800