~~0000072741es:WaterDistributionSegmentMemberes:WholesaleMarketSalesRevenueMemberus-gaap:OperatingSegmentsMember2021-04-012021-06-30~~



	UNITED STATES SECURITIES AND EXCHANGE COMMISSION WASHINGTON, D.C. 20549
	FORM	10-Q
☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the Quarterly Period Ended	~~June 30, 2022~~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

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 ~~July 31, 2022~~April 30, 2023

Eversource Energy Common Shares, $5.00 par value	~~346,443,316~~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 ~~2021~~2022 Form 10-K			The Eversource Energy and Subsidiaries ~~2021~~2022 combined Annual Report on Form 10-K as filed with the SEC
Fitch			Fitch Ratings, Inc.


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			~~One million~~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

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	4035
	The Connecticut Light and Power Company, NSTAR Electric Company and Subsidiary, and Public Service Company of New Hampshire and Subsidiaries	5549

ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	6354

ITEM 4.	Controls and Procedures	6354

PART II – OTHER INFORMATION

ITEM 1.	Legal Proceedings	6455

ITEM 1A.	Risk Factors	6455

ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	6455

ITEM 6.	Exhibits	6556

SIGNATURES		6757

iii

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	(Thousands of Dollars)	As of June 30, 2022		As of December 31, 2021		(Thousands of Dollars)	As of March 31, 2023		As of December 31, 2022

ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash	Cash	$	29,540	$	66,773	Cash	$	35,975	$	47,597
Receivables, Net (net of allowance for uncollectible accounts of $457,846 and $417,406 as of June 30, 2022 and December 31, 2021, respectively)		1,345,904		1,226,069
Cash Equivalents						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)						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	Unbilled Revenues	177,472		210,879		Unbilled Revenues	216,715		238,968
Fuel, Materials, Supplies and REC Inventory		262,421		267,547
Materials, Supplies, Natural Gas and REC Inventory						Materials, Supplies, Natural Gas and REC Inventory	423,343		374,395
Regulatory Assets	Regulatory Assets	1,163,411		1,129,093		Regulatory Assets	1,332,028		1,335,491

Prepayments and Other Current Assets	Prepayments and Other Current Assets	289,295		369,759		Prepayments and Other Current Assets	468,292		382,603
Total Current Assets	Total Current Assets	3,268,043		3,270,120		Total Current Assets	4,136,429		4,223,198
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net	34,407,210		33,377,650		Property, Plant and Equipment, Net	36,744,855		36,112,820
Deferred Debits and Other Assets:	Deferred Debits and Other Assets:					Deferred Debits and Other Assets:
Regulatory Assets	Regulatory Assets	4,569,236		4,586,709		Regulatory Assets	4,407,875		4,242,794
Goodwill	Goodwill	4,477,756		4,477,269		Goodwill	4,522,632		4,522,632
Investments in Unconsolidated Affiliates	Investments in Unconsolidated Affiliates	1,719,878		1,436,293		Investments in Unconsolidated Affiliates	2,302,880		2,176,080
Prepaid Pension and PBOP	Prepaid Pension and PBOP	446,780		271,987		Prepaid Pension and PBOP	1,097,814		1,045,524
Marketable Securities	Marketable Securities	400,516		460,347		Marketable Securities	332,050		366,508
Other Long-Term Assets	Other Long-Term Assets	626,821		611,769		Other Long-Term Assets	560,632		541,344
Total Deferred Debits and Other Assets	Total Deferred Debits and Other Assets	12,240,987		11,844,374		Total Deferred Debits and Other Assets	13,223,883		12,894,882
Total Assets	Total Assets	$	49,916,240	$	48,492,144	Total Assets	$	54,105,167	$	53,230,900

LIABILITIES AND CAPITALIZATION	LIABILITIES AND CAPITALIZATION					LIABILITIES AND CAPITALIZATION
Current Liabilities:	Current Liabilities:					Current Liabilities:
Notes Payable	Notes Payable	$	98,800	$	1,505,450	Notes Payable	$	1,195,500	$	1,442,200
Long-Term Debt – Current Portion	Long-Term Debt – Current Portion	1,265,463		1,193,097		Long-Term Debt – Current Portion	1,615,461		1,320,129
Rate Reduction Bonds – Current Portion	Rate Reduction Bonds – Current Portion	43,210		43,210		Rate Reduction Bonds – Current Portion	43,210		43,210
Accounts Payable	Accounts Payable	1,353,506		1,672,230		Accounts Payable	1,821,911		2,113,905

Regulatory Liabilities	Regulatory Liabilities	759,733		602,432		Regulatory Liabilities	650,538		890,786
Other Current Liabilities	Other Current Liabilities	739,833		830,620		Other Current Liabilities	1,078,421		989,053
Total Current Liabilities	Total Current Liabilities	4,260,545		5,847,039		Total Current Liabilities	6,405,041		6,799,283
Deferred Credits and Other Liabilities:	Deferred Credits and Other Liabilities:					Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	Accumulated Deferred Income Taxes	4,770,063		4,597,120		Accumulated Deferred Income Taxes	5,239,443		5,067,902
Regulatory Liabilities	Regulatory Liabilities	3,886,914		3,866,251		Regulatory Liabilities	3,974,374		3,930,305
Derivative Liabilities	Derivative Liabilities	188,736		235,387		Derivative Liabilities	124,281		143,929
Asset Retirement Obligations	Asset Retirement Obligations	505,055		500,111		Asset Retirement Obligations	500,695		502,713
Accrued Pension, SERP and PBOP	Accrued Pension, SERP and PBOP	194,546		242,463		Accrued Pension, SERP and PBOP	120,200		135,473
Other Long-Term Liabilities	Other Long-Term Liabilities	881,729		971,080		Other Long-Term Liabilities	884,717		888,081
Total Deferred Credits and Other Liabilities	Total Deferred Credits and Other Liabilities	10,427,043		10,412,412		Total Deferred Credits and Other Liabilities	10,843,710		10,668,403
Long-Term Debt	Long-Term Debt	19,583,770		17,023,577		Long-Term Debt	20,562,588		19,723,994
Rate Reduction Bonds	Rate Reduction Bonds	432,097		453,702		Rate Reduction Bonds	388,887		410,492
Noncontrolling Interest – Preferred Stock of Subsidiaries	Noncontrolling Interest – Preferred Stock of Subsidiaries	155,570		155,570		Noncontrolling Interest – Preferred Stock of Subsidiaries	155,570		155,570
Common Shareholders' Equity:	Common Shareholders' Equity:					Common Shareholders' Equity:
Common Shares	Common Shares	1,796,056		1,789,092		Common Shares	1,799,920		1,799,920
Capital Surplus, Paid In	Capital Surplus, Paid In	8,242,346		8,098,514		Capital Surplus, Paid In	8,412,085		8,401,731
Retained Earnings	Retained Earnings	5,301,054		5,005,391		Retained Earnings	5,782,958		5,527,153
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss	(42,864)		(42,275)		Accumulated Other Comprehensive Loss	(36,191)		(39,421)
Treasury Stock	Treasury Stock	(239,377)		(250,878)		Treasury Stock	(209,401)		(216,225)
Common Shareholders' Equity	Common Shareholders' Equity	15,057,215		14,599,844		Common Shareholders' Equity	15,749,371		15,473,158
Commitments and Contingencies (Note 9)	Commitments and Contingencies (Note 9)	0		0		Commitments and Contingencies (Note 9)
Total Liabilities and Capitalization	Total Liabilities and Capitalization	$	49,916,240	$	48,492,144	Total Liabilities and Capitalization	$	54,105,167	$	53,230,900

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

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


		For the Three Months Ended June 30,				For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars, Except Share Information)	(Thousands of Dollars, Except Share Information)	2022		2021		2022		2021		(Thousands of Dollars, Except Share Information)		2023		2022

Operating Revenues	Operating Revenues	$	2,572,641	$	2,122,538	$	6,043,951	$	4,948,378	Operating Revenues		$	3,795,643	$	3,471,310

Operating Expenses:	Operating Expenses:									Operating Expenses:
Purchased Power, Fuel and Transmission		940,541		650,087		2,330,237		1,648,578
Purchased Power, Purchased Natural Gas and Transmission										Purchased Power, Purchased Natural Gas and Transmission		1,903,246		1,389,696
Operations and Maintenance	Operations and Maintenance	452,174		411,147		924,608		876,689		Operations and Maintenance		454,562		472,433
Depreciation	Depreciation	294,238		274,647		583,568		545,352		Depreciation		312,955		289,330
Amortization	Amortization	70,409		5,611		307,357		113,624		Amortization		(76,059)		236,948
Energy Efficiency Programs	Energy Efficiency Programs	136,679		128,955		336,163		317,018		Energy Efficiency Programs		222,952		199,484
Taxes Other Than Income Taxes	Taxes Other Than Income Taxes	223,031		200,486		443,395		409,944		Taxes Other Than Income Taxes		228,414		220,364
Total Operating Expenses	Total Operating Expenses	2,117,072		1,670,933		4,925,328		3,911,205		Total Operating Expenses		3,046,070		2,808,255
Operating Income	Operating Income	455,569		451,605		1,118,623		1,037,173		Operating Income		749,573		663,055
Interest Expense	Interest Expense	160,090		145,435		313,334		283,201		Interest Expense		194,543		153,245
Other Income, Net	Other Income, Net	93,861		46,619		165,422		80,820		Other Income, Net		88,981		71,561
Income Before Income Tax Expense	Income Before Income Tax Expense	389,340		352,789		970,711		834,792		Income Before Income Tax Expense		644,011		581,371
Income Tax Expense	Income Tax Expense	95,598		86,389		231,643		200,370		Income Tax Expense		150,972		136,045
Net Income	Net Income	293,742		266,400		739,068		634,422		Net Income		493,039		445,326
Net Income Attributable to Noncontrolling Interests	Net Income Attributable to Noncontrolling Interests	1,880		1,880		3,759		3,759		Net Income Attributable to Noncontrolling Interests		1,880		1,880
Net Income Attributable to Common Shareholders	Net Income Attributable to Common Shareholders	$	291,862	$	264,520	$	735,309	$	630,663	Net Income Attributable to Common Shareholders		$	491,159	$	443,446

Basic and Diluted Earnings Per Common Share	Basic and Diluted Earnings Per Common Share	$	0.84	$	0.77	$	2.13	$	1.83	Basic and Diluted Earnings Per Common Share		$	1.41	$	1.28

Weighted Average Common Shares Outstanding:	Weighted Average Common Shares Outstanding:									Weighted Average Common Shares Outstanding:
Basic	Basic	345,893,714		343,844,626		345,525,030		343,761,435		Basic		349,217,147		345,156,346
Diluted	Diluted	346,295,478		344,435,696		345,978,306		344,385,193		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 June 30, For the Six Months Ended June 30,
(Thousands of Dollars) 2022 2021 2022 2021
Net Income $ 293,742 $ 266,400 $ 739,068 $ 634,422
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments 5 445 10 852
Changes in Unrealized (Losses)/Gains on
   Marketable Securities (505) 273 (1,323) (463)
Changes in Funded Status of Pension, SERP and
   PBOP Benefit Plans (793) 163 724 1,680
Other Comprehensive (Loss)/Income, Net of Tax (1,293) 881 (589) 2,069
Comprehensive Income Attributable to
   Noncontrolling Interests (1,880) (1,880) (3,759) (3,759)
Comprehensive Income Attributable to Common
   Shareholders $ 290,569 $ 265,401 $ 734,720 $ 632,732


	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.

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

(Unaudited)


		For the Six Months Ended June 30, 2022														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			Common Shares			Capital Surplus, Paid In		Retained Earnings		Accumulated Other Comprehensive Loss		Treasury Stock		Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information)	(Thousands of Dollars, Except Share Information)	Shares	Amount												(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
Balance as of January 1, 2023															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	Net Income						445,326						445,326		Net Income						493,039						493,039
Dividends on Common Shares - $0.6375 Per Share							(219,768)						(219,768)
Dividends on Common Shares - $0.675 Per Share															Dividends on Common Shares - $0.675 Per Share						(235,354)						(235,354)
Dividends on Preferred Stock	Dividends on Preferred Stock						(1,880)						(1,880)		Dividends on Preferred Stock						(1,880)						(1,880)
Long-Term Incentive Plan Activity	Long-Term Incentive Plan Activity				(16,538)								(16,538)		Long-Term Incentive Plan Activity				(13,141)								(13,141)
Issuance of Treasury Shares	Issuance of Treasury Shares	447,076			20,642						8,360		29,002		Issuance of Treasury Shares	364,227			23,495						6,824		30,319

Other Comprehensive Income	Other Comprehensive Income								704				704		Other Comprehensive Income								3,230				3,230
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
Net Income							293,742						293,742
Dividends on Common Shares - $0.6375 Per Share							(219,877)						(219,877)
Dividends on Preferred Stock							(1,880)						(1,880)
Issuance of Common Shares - $5 par value		1,392,804	6,964		121,142								128,106
Long-Term Incentive Plan Activity					9,070								9,070
Issuance of Treasury Shares		167,953			11,340						3,141		14,481
Capital Stock Expense					(1,824)								(1,824)
Other Comprehensive Loss									(1,293)				(1,293)
Balance as of June 30, 2022		346,411,029	$	1,796,056	$	8,242,346	$	5,301,054	$	(42,864)	$	(239,377)	$	15,057,215
Balance as of March 31, 2023															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 Six Months Ended June 30, 2021														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			Common Shares			Capital Surplus, Paid In		Retained Earnings		Accumulated Other Comprehensive Loss		Treasury Stock		Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information)	(Thousands of Dollars, Except Share Information)	Shares	Amount												(Thousands of Dollars, Except Share Information)	Shares	Amount
Balance as of January 1, 2021		342,954,023	$	1,789,092	$	8,015,663	$	4,613,201	$	(76,411)	$	(277,979)	$	14,063,566
Balance as of January 1, 2022															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	Net Income						368,023						368,023		Net Income						445,326						445,326
Dividends on Common Shares - $0.6025 Per Share							(206,913)						(206,913)
Dividends on Common Shares - $0.6375 Per Share															Dividends on Common Shares - $0.6375 Per Share						(219,768)						(219,768)
Dividends on Preferred Stock	Dividends on Preferred Stock						(1,880)						(1,880)		Dividends on Preferred Stock						(1,880)						(1,880)
Long-Term Incentive Plan Activity	Long-Term Incentive Plan Activity				(15,727)								(15,727)		Long-Term Incentive Plan Activity				(16,538)								(16,538)
Issuance of Treasury Shares	Issuance of Treasury Shares	480,275			16,182						8,981		25,163		Issuance of Treasury Shares	447,076			20,642						8,360		29,002
Other Comprehensive Income	Other Comprehensive Income								1,188				1,188		Other Comprehensive Income								704				704
Balance as of March 31, 2021		343,434,298	1,789,092		8,016,118		4,772,431		(75,223)		(268,998)		14,233,420
Net Income							266,400						266,400
Dividends on Common Shares - $0.6025 Per Share							(206,893)						(206,893)
Dividends on Preferred Stock							(1,880)						(1,880)
Long-Term Incentive Plan Activity					6,162								6,162

Issuance of Treasury Shares		166,805			10,679						3,120		13,799

Other Comprehensive Income									881				881
Balance as of June 30, 2021		343,601,103	$	1,789,092	$	8,032,959	$	4,830,058	$	(74,342)	$	(265,878)	$	14,311,889
Balance as of March 31, 2022															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.

EVERSOURCE ENERGY AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


		For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		(Thousands of Dollars)	2023		2022

Operating Activities:	Operating Activities:					Operating Activities:
Net Income	Net Income	$	739,068	$	634,422	Net Income	$	493,039	$	445,326
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:					Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	Depreciation	583,568		545,352		Depreciation	312,955		289,330
Deferred Income Taxes	Deferred Income Taxes	126,970		120,390		Deferred Income Taxes	149,197		67,557
Uncollectible Expense	Uncollectible Expense	30,032		27,683		Uncollectible Expense	22,821		17,135
Pension, SERP and PBOP Income, Net	Pension, SERP and PBOP Income, Net	(80,404)		(6,391)		Pension, SERP and PBOP Income, Net	(24,563)		(40,642)
Pension and PBOP Contributions		(52,400)		(72,400)
Regulatory (Under)/Over Recoveries, Net		(226,238)		18,252
(Customer Credits)/Reserve at CL&P related to PURA Settlement Agreement and Storm Performance Penalty		(64,909)		28,583
Pension Contributions						Pension Contributions	(1,100)		(26,100)
Regulatory Under Recoveries, Net						Regulatory Under Recoveries, Net	(158,964)		(107,767)
Customer Credits at CL&P related to PURA Settlement Agreement and Storm Performance Penalty						Customer Credits at CL&P related to PURA Settlement Agreement and Storm Performance Penalty	—		(58,412)
Amortization	Amortization	307,357		113,624		Amortization	(76,059)		236,948

Cost of Removal Expenditures	Cost of Removal Expenditures	(169,863)		(95,593)		Cost of Removal Expenditures	(70,514)		(61,660)
Other	Other	(75,916)		(58,472)		Other	(54,486)		(21,409)
Changes in Current Assets and Liabilities:	Changes in Current Assets and Liabilities:					Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	Receivables and Unbilled Revenues, Net	(176,132)		(85,261)		Receivables and Unbilled Revenues, Net	(225,609)		(291,723)

Taxes Receivable/Accrued, Net	Taxes Receivable/Accrued, Net	85,071		(9,113)		Taxes Receivable/Accrued, Net	284		56,519
Accounts Payable	Accounts Payable	(83,550)		(285,670)		Accounts Payable	(258,476)		(68,909)
Other Current Assets and Liabilities, Net	Other Current Assets and Liabilities, Net	(100,835)		(67,961)		Other Current Assets and Liabilities, Net	(39,368)		(64,253)
Net Cash Flows Provided by Operating Activities	Net Cash Flows Provided by Operating Activities	841,819		807,445		Net Cash Flows Provided by Operating Activities	69,157		371,940

Investing Activities:	Investing Activities:					Investing Activities:
Investments in Property, Plant and Equipment	Investments in Property, Plant and Equipment	(1,549,081)		(1,423,223)		Investments in Property, Plant and Equipment	(977,144)		(764,594)
Proceeds from Sales of Marketable Securities	Proceeds from Sales of Marketable Securities	168,997		253,842		Proceeds from Sales of Marketable Securities	64,307		90,409
Purchases of Marketable Securities	Purchases of Marketable Securities	(152,741)		(240,729)		Purchases of Marketable Securities	(56,508)		(76,182)
Investments in Unconsolidated Affiliates, Net		(277,001)		(100,527)
Investments in Unconsolidated Affiliates						Investments in Unconsolidated Affiliates	(87,845)		(113,856)
Other Investing Activities	Other Investing Activities	10,771		12,661		Other Investing Activities	5,640		5,976
Net Cash Flows Used in Investing Activities	Net Cash Flows Used in Investing Activities	(1,799,055)		(1,497,976)		Net Cash Flows Used in Investing Activities	(1,051,550)		(858,247)

Financing Activities:	Financing Activities:					Financing Activities:
Issuance of Common Shares, Net of Issuance Costs		126,282		—

Cash Dividends on Common Shares	Cash Dividends on Common Shares	(427,931)		(402,211)		Cash Dividends on Common Shares	(229,405)		(213,890)
Cash Dividends on Preferred Stock	Cash Dividends on Preferred Stock	(3,759)		(3,759)		Cash Dividends on Preferred Stock	(1,880)		(1,880)
(Decrease)/Increase in Notes Payable	(Decrease)/Increase in Notes Payable	(1,317,950)		753,175		(Decrease)/Increase in Notes Payable	(246,700)		163,350
Repayment of Rate Reduction Bonds	Repayment of Rate Reduction Bonds	(21,605)		(21,605)		Repayment of Rate Reduction Bonds	(21,605)		(21,605)
Issuance of Long-Term Debt	Issuance of Long-Term Debt	3,350,000		1,525,000		Issuance of Long-Term Debt	1,550,000		1,300,000
Retirement of Long-Term Debt	Retirement of Long-Term Debt	(770,000)		(1,022,000)		Retirement of Long-Term Debt	(400,000)		(770,000)
Other Financing Activities	Other Financing Activities	(42,133)		(35,008)		Other Financing Activities	(27,002)		(26,087)
Net Cash Flows Provided by Financing Activities	Net Cash Flows Provided by Financing Activities	892,904		793,592		Net Cash Flows Provided by Financing Activities	623,408		429,888
Net (Decrease)/Increase in Cash and Restricted Cash		(64,332)		103,061
Cash and Restricted Cash - Beginning of Period		221,008		264,950
Net Decrease in Cash, Cash Equivalents and Restricted Cash						Net Decrease in Cash, Cash Equivalents and Restricted Cash	(358,985)		(56,419)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period						Cash, Cash Equivalents and Restricted Cash - Beginning of Period	521,752		221,008
Cash and Restricted Cash - End of Period	Cash and Restricted Cash - End of Period	$	156,676	$	368,011	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.

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	(Thousands of Dollars)	As of June 30, 2022		As of December 31, 2021		(Thousands of Dollars)	As of March 31, 2023		As of December 31, 2022

ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash	Cash	$	9,203	$	55,804	Cash	$	9,340	$	11,312
Receivables, Net (net of allowance for uncollectible accounts of $192,744 and $181,319 as of June 30, 2022 and December 31, 2021, respectively)		596,847		447,774
Receivables, Net (net of allowance for uncollectible accounts of $253,376 and $225,320 as of March 31, 2023 and December 31, 2022, respectively)						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	Accounts Receivable from Affiliated Companies	39,881		43,944		Accounts Receivable from Affiliated Companies	69,095		46,439
Unbilled Revenues	Unbilled Revenues	52,711		56,787		Unbilled Revenues	54,048		59,363
Materials and Supplies	Materials and Supplies	75,004		60,264		Materials and Supplies	103,987		88,157
Taxes Receivable						Taxes Receivable	26,723		65,785
Regulatory Assets	Regulatory Assets	396,447		371,609		Regulatory Assets	356,468		314,089

Prepayments and Other Current Assets	Prepayments and Other Current Assets	74,350		120,257		Prepayments and Other Current Assets	93,078		62,524
Total Current Assets	Total Current Assets	1,244,443		1,156,439		Total Current Assets	1,345,787		1,259,721
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net	11,090,981		10,803,543		Property, Plant and Equipment, Net	11,630,278		11,467,024
Deferred Debits and Other Assets:	Deferred Debits and Other Assets:					Deferred Debits and Other Assets:
Regulatory Assets	Regulatory Assets	1,663,820		1,713,161		Regulatory Assets	1,639,960		1,593,693
Prepaid Pension						Prepaid Pension	155,856		147,914
Other Long-Term Assets	Other Long-Term Assets	307,045		276,513		Other Long-Term Assets	302,817		290,444
Total Deferred Debits and Other Assets	Total Deferred Debits and Other Assets	1,970,865		1,989,674		Total Deferred Debits and Other Assets	2,098,633		2,032,051
Total Assets	Total Assets	$	14,306,289	$	13,949,656	Total Assets	$	15,074,698	$	14,758,796

LIABILITIES AND CAPITALIZATION	LIABILITIES AND CAPITALIZATION					LIABILITIES AND CAPITALIZATION
Current Liabilities:	Current Liabilities:					Current Liabilities:
Notes Payable to Eversource Parent	Notes Payable to Eversource Parent	$	67,500	$	—	Notes Payable to Eversource Parent	$	318,000	$	—
Long-Term Debt – Current Portion		400,000		—

Accounts Payable	Accounts Payable	450,260		533,454		Accounts Payable	622,024		710,500
Accounts Payable to Affiliated Companies	Accounts Payable to Affiliated Companies	92,316		132,578		Accounts Payable to Affiliated Companies	141,792		136,277

Regulatory Liabilities	Regulatory Liabilities	337,240		266,489		Regulatory Liabilities	124,640		336,048

Derivative Liabilities	Derivative Liabilities	75,872		73,528		Derivative Liabilities	85,105		81,588
Other Current Liabilities	Other Current Liabilities	140,253		141,955		Other Current Liabilities	205,692		163,875
Total Current Liabilities	Total Current Liabilities	1,563,441		1,148,004		Total Current Liabilities	1,497,253		1,428,288
Deferred Credits and Other Liabilities:	Deferred Credits and Other Liabilities:					Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	Accumulated Deferred Income Taxes	1,594,027		1,562,102		Accumulated Deferred Income Taxes	1,740,504		1,640,034
Regulatory Liabilities	Regulatory Liabilities	1,217,711		1,193,259		Regulatory Liabilities	1,277,281		1,263,396
Derivative Liabilities	Derivative Liabilities	188,736		235,387		Derivative Liabilities	124,281		143,929

Other Long-Term Liabilities	Other Long-Term Liabilities	180,950		179,824		Other Long-Term Liabilities	160,104		166,081
Total Deferred Credits and Other Liabilities	Total Deferred Credits and Other Liabilities	3,181,424		3,170,572		Total Deferred Credits and Other Liabilities	3,302,170		3,213,440
Long-Term Debt	Long-Term Debt	3,815,946		4,215,379		Long-Term Debt	4,310,233		4,216,488
Preferred Stock Not Subject to Mandatory Redemption	Preferred Stock Not Subject to Mandatory Redemption	116,200		116,200		Preferred Stock Not Subject to Mandatory Redemption	116,200		116,200
Common Stockholder's Equity:	Common Stockholder's Equity:					Common Stockholder's Equity:
Common Stock	Common Stock	60,352		60,352		Common Stock	60,352		60,352
Capital Surplus, Paid In	Capital Surplus, Paid In	3,210,765		3,010,765		Capital Surplus, Paid In	3,260,765		3,260,765
Retained Earnings	Retained Earnings	2,357,968		2,228,133		Retained Earnings	2,527,520		2,463,094
Accumulated Other Comprehensive Income	Accumulated Other Comprehensive Income	193		251		Accumulated Other Comprehensive Income	205		169
Common Stockholder's Equity	Common Stockholder's Equity	5,629,278		5,299,501		Common Stockholder's Equity	5,848,842		5,784,380
Commitments and Contingencies (Note 9)	Commitments and Contingencies (Note 9)	0		0		Commitments and Contingencies (Note 9)
Total Liabilities and Capitalization	Total Liabilities and Capitalization	$	14,306,289	$	13,949,656	Total Liabilities and Capitalization	$	15,074,698	$	14,758,796

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF INCOME

(Unaudited)


		For the Three Months Ended June 30,				For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		2022		2021		(Thousands of Dollars)		2023		2022

Operating Revenues	Operating Revenues	$	1,035,682	$	829,597	$	2,321,514	$	1,816,871	Operating Revenues		$	1,338,905	$	1,285,831

Operating Expenses:	Operating Expenses:									Operating Expenses:
Purchased Power and Transmission	Purchased Power and Transmission	421,000		308,137		944,463		681,411		Purchased Power and Transmission		850,564		523,463
Operations and Maintenance	Operations and Maintenance	169,004		152,394		326,065		327,814		Operations and Maintenance		160,316		157,061
Depreciation	Depreciation	88,233		84,423		175,498		167,828		Depreciation		92,237		87,265
Amortization of Regulatory Assets/(Liabilities), Net		42,772		(15,059)		212,522		47,716
Amortization of Regulatory (Liabilities)/Assets, Net										Amortization of Regulatory (Liabilities)/Assets, Net		(122,315)		169,749
Energy Efficiency Programs	Energy Efficiency Programs	29,780		29,524		65,177		65,097		Energy Efficiency Programs		32,646		35,397
Taxes Other Than Income Taxes	Taxes Other Than Income Taxes	95,778		83,886		186,151		175,278		Taxes Other Than Income Taxes		101,584		90,373
Total Operating Expenses	Total Operating Expenses	846,567		643,305		1,909,876		1,465,144		Total Operating Expenses		1,115,032		1,063,308
Operating Income	Operating Income	189,115		186,292		411,638		351,727		Operating Income		223,873		222,523
Interest Expense	Interest Expense	42,175		42,614		82,761		81,592		Interest Expense		45,201		40,586
Other Income, Net	Other Income, Net	19,800		9,879		39,363		14,787		Other Income, Net		14,937		19,564
Income Before Income Tax Expense	Income Before Income Tax Expense	166,740		153,557		368,240		284,922		Income Before Income Tax Expense		193,609		201,501
Income Tax Expense	Income Tax Expense	40,902		38,001		89,426		70,967		Income Tax Expense		45,193		48,524
Net Income	Net Income	$	125,838	$	115,556	$	278,814	$	213,955	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 June 30,				For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		2022		2021		(Thousands of Dollars)		2023		2022

Net Income	Net Income	$	125,838	$	115,556	$	278,814	$	213,955	Net Income		$	148,416	$	152,977
Other Comprehensive (Loss)/Income, Net of Tax:
Other Comprehensive Income/(Loss), Net of Tax:										Other Comprehensive Income/(Loss), Net of Tax:
Qualified Cash Flow Hedging Instruments	Qualified Cash Flow Hedging Instruments	(7)		(6)		(13)		(13)		Qualified Cash Flow Hedging Instruments		(7)		(7)
Changes in Unrealized (Losses)/Gains on Marketable Securities		(16)		9		(45)		(16)
Other Comprehensive (Loss)/Income, Net of Tax		(23)		3		(58)		(29)
Changes in Unrealized Gains/(Losses) on Marketable Securities										Changes in Unrealized Gains/(Losses) on Marketable Securities		43		(28)
Other Comprehensive Income/(Loss), Net of Tax										Other Comprehensive Income/(Loss), Net of Tax		36		(35)
Comprehensive Income	Comprehensive Income	$	125,815	$	115,559	$	278,756	$	213,926	Comprehensive Income		$	148,452	$	152,942

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

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)


		For the Six Months Ended June 30, 2022																			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				Common Stock					Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Income			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	(Thousands of Dollars, Except Stock Information)	Stock	Amount								(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
Balance as of January 1, 2023																				Balance as of January 1, 2023	6,035,205			$	60,352		$	3,260,765		$	2,463,094		$	169		$	5,784,380
Net Income	Net Income								152,977								152,977			Net Income									148,416						148,416
Dividends on Preferred Stock	Dividends on Preferred Stock								(1,390)								(1,390)			Dividends on Preferred Stock									(1,390)						(1,390)
Dividends on Common Stock	Dividends on Common Stock								(73,100)								(73,100)			Dividends on Common Stock									(82,600)						(82,600)
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
Net Income									125,838								125,838
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													(23)				(23)
Balance as of June 30, 2022		6,035,205	$	60,352	$	3,210,765			$	2,357,968			$	193			$	5,629,278

Other Comprehensive Income																				Other Comprehensive Income												36			36
Balance as of March 31, 2023																				Balance as of March 31, 2023	6,035,205			$	60,352	$	3,260,765		$	2,527,520		$	205		$	5,848,842


		For the Six Months Ended June 30, 2021																			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				Common Stock					Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Income			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	(Thousands of Dollars, Except Stock Information)	Stock	Amount								(Thousands of Dollars, Except Stock Information)	Stock								Amount
Balance as of January 1, 2021		6,035,205	$	60,352			$	2,810,765							$	2,173,367			$	302		$	5,044,786
Balance as of January 1, 2022																				Balance as of January 1, 2022	6,035,205			$	60,352		$	3,010,765		$	2,228,133		$	251		$	5,299,501
Net Income	Net Income								98,398								98,398			Net Income									152,977						152,977
Dividends on Preferred Stock	Dividends on Preferred Stock								(1,390)								(1,390)			Dividends on Preferred Stock									(1,390)						(1,390)
Dividends on Common Stock	Dividends on Common Stock								(70,100)								(70,100)			Dividends on Common Stock									(73,100)						(73,100)
Capital Contributions from Eversource Parent																				Capital Contributions from Eversource Parent						100,000									100,000
Other Comprehensive Loss	Other Comprehensive Loss												(32)				(32)			Other Comprehensive Loss												(35)			(35)
Balance as of March 31, 2021		6,035,205	60,352		2,810,765				2,200,275				270				5,071,662
Net Income									115,556								115,556
Dividends on Preferred Stock									(1,390)								(1,390)
Dividends on Common Stock									(70,100)								(70,100)
Other Comprehensive Income													3				3
Balance as of June 30, 2021		6,035,205	$	60,352	$	2,810,765			$	2,244,341			$	273			$	5,115,731
Balance as of March 31, 2022																				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.

THE CONNECTICUT LIGHT AND POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)


		For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		(Thousands of Dollars)	2023		2022

Operating Activities:	Operating Activities:					Operating Activities:
Net Income	Net Income	$	278,814	$	213,955	Net Income	$	148,416	$	152,977
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:						Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	Depreciation	175,498		167,828		Depreciation	92,237		87,265
Deferred Income Taxes	Deferred Income Taxes	15,782		41,886		Deferred Income Taxes	94,267		19,627
Uncollectible Expense	Uncollectible Expense	6,701		6,614		Uncollectible Expense	3,876		3,776
Pension, SERP, and PBOP (Income)/Expense, Net		(14,532)		3,803
Pension Contributions		—		(37,880)
Regulatory Underrecoveries, Net		(141,830)		(50,704)
(Customer Credits)/Reserve related to PURA Settlement Agreement and Storm Performance Penalty		(64,909)		28,583
Amortization of Regulatory Assets, Net		212,522		47,716
Pension, SERP, and PBOP Income, Net						Pension, SERP, and PBOP Income, Net	(4,461)		(7,330)

Regulatory Under Recoveries, Net						Regulatory Under Recoveries, Net	(110,114)		(162,474)
Customer Credits related to PURA Settlement Agreement and Storm Performance Penalty						Customer Credits related to PURA Settlement Agreement and Storm Performance Penalty	—		(58,412)
Amortization of Regulatory (Liabilities)/Assets, Net						Amortization of Regulatory (Liabilities)/Assets, Net	(122,315)		169,749
Cost of Removal Expenditures	Cost of Removal Expenditures	(37,103)		(38,031)		Cost of Removal Expenditures	(13,011)		(16,684)
Other	Other	(23,311)		(24,106)		Other	(13,964)		(9,357)
Changes in Current Assets and Liabilities:	Changes in Current Assets and Liabilities:					Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	Receivables and Unbilled Revenues, Net	(170,500)		(104,262)		Receivables and Unbilled Revenues, Net	(76,482)		(125,429)
Taxes Receivable/Accrued, Net	Taxes Receivable/Accrued, Net	18,735		33,049		Taxes Receivable/Accrued, Net	52,261		67,708
Accounts Payable	Accounts Payable	(20,845)		(80,007)		Accounts Payable	(110,926)		38,010
Other Current Assets and Liabilities, Net	Other Current Assets and Liabilities, Net	3,563		15,513		Other Current Assets and Liabilities, Net	(13,412)		(24,143)
Net Cash Flows Provided by Operating Activities		238,585		223,957
Net Cash Flows (Used in)/Provided by Operating Activities						Net Cash Flows (Used in)/Provided by Operating Activities	(73,628)		135,283

Investing Activities:	Investing Activities:					Investing Activities:
Investments in Property, Plant and Equipment	Investments in Property, Plant and Equipment	(414,407)		(393,323)		Investments in Property, Plant and Equipment	(255,905)		(205,343)
Other Investing Activities	Other Investing Activities	424		157		Other Investing Activities	126		346
Net Cash Flows Used in Investing Activities	Net Cash Flows Used in Investing Activities	(413,983)		(393,166)		Net Cash Flows Used in Investing Activities	(255,779)		(204,997)

Financing Activities:	Financing Activities:					Financing Activities:
Cash Dividends on Common Stock	Cash Dividends on Common Stock	(146,200)		(140,200)		Cash Dividends on Common Stock	(82,600)		(73,100)
Cash Dividends on Preferred Stock	Cash Dividends on Preferred Stock	(2,779)		(2,779)		Cash Dividends on Preferred Stock	(1,390)		(1,390)
Capital Contributions from Eversource Parent	Capital Contributions from Eversource Parent	200,000		—		Capital Contributions from Eversource Parent	—		100,000
Issuance of Long-Term Debt	Issuance of Long-Term Debt	—		425,000		Issuance of Long-Term Debt	500,000		—
Retirement of Long-Term Debt						Retirement of Long-Term Debt	(400,000)		—

Increase in Notes Payable to Eversource Parent	Increase in Notes Payable to Eversource Parent	67,500		—		Increase in Notes Payable to Eversource Parent	318,000		—
Other Financing Activities	Other Financing Activities	—		(5,180)		Other Financing Activities	(6,521)		—
Net Cash Flows Provided by Financing Activities	Net Cash Flows Provided by Financing Activities	118,521		276,841		Net Cash Flows Provided by Financing Activities	327,489		25,510
Net (Decrease)/Increase in Cash and Restricted Cash		(56,877)		107,632
Net Decrease in Cash and Restricted Cash						Net Decrease in Cash and Restricted Cash	(1,918)		(44,204)
Cash and Restricted Cash - Beginning of Period	Cash and Restricted Cash - Beginning of Period	74,788		99,809		Cash and Restricted Cash - Beginning of Period	20,327		74,788
Cash and Restricted Cash - End of Period	Cash and Restricted Cash - End of Period	$	17,911	$	207,441	Cash and Restricted Cash - End of Period	$	18,409	$	30,584

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	(Thousands of Dollars)	As of June 30, 2022		As of December 31, 2021		(Thousands of Dollars)	As of March 31, 2023		As of December 31, 2022

ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash	Cash	$	5,349	$	745	Cash	$	618	$	738
Receivables, Net (net of allowance for uncollectible accounts of $100,534 and $97,005 as of June 30, 2022 and December 31, 2021, respectively)		397,799		405,674
Cash Equivalents						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)						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	Accounts Receivable from Affiliated Companies	27,235		67,420		Accounts Receivable from Affiliated Companies	59,062		35,196
Unbilled Revenues	Unbilled Revenues	47,088		37,497		Unbilled Revenues	43,091		39,680
Materials, Supplies and REC Inventory	Materials, Supplies and REC Inventory	71,229		116,712		Materials, Supplies and REC Inventory	190,301		138,352
Taxes Receivable		22,329		80,617

Regulatory Assets	Regulatory Assets	419,718		443,956		Regulatory Assets	559,758		492,759
Prepayments and Other Current Assets	Prepayments and Other Current Assets	28,303		22,397		Prepayments and Other Current Assets	62,149		71,276
Total Current Assets	Total Current Assets	1,019,050		1,175,018		Total Current Assets	1,415,964		1,558,378
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net	11,149,405		10,876,614		Property, Plant and Equipment, Net	11,819,012		11,626,968
Deferred Debits and Other Assets:	Deferred Debits and Other Assets:					Deferred Debits and Other Assets:
Regulatory Assets	Regulatory Assets	1,260,785		1,135,231		Regulatory Assets	1,263,534		1,221,619
Prepaid Pension and PBOP	Prepaid Pension and PBOP	484,746		441,426		Prepaid Pension and PBOP	596,214		576,809
Other Long-Term Assets	Other Long-Term Assets	179,517		171,657		Other Long-Term Assets	118,185		111,846
Total Deferred Debits and Other Assets	Total Deferred Debits and Other Assets	1,925,048		1,748,314		Total Deferred Debits and Other Assets	1,977,933		1,910,274
Total Assets	Total Assets	$	14,093,503	$	13,799,946	Total Assets	$	15,212,909	$	15,095,620

LIABILITIES AND CAPITALIZATION	LIABILITIES AND CAPITALIZATION					LIABILITIES AND CAPITALIZATION
Current Liabilities:	Current Liabilities:					Current Liabilities:
Notes Payable	Notes Payable	$	63,000	$	162,500	Notes Payable	$	147,500	$	—
Notes Payable to Eversource Parent		3,200		—

Long-Term Debt – Current Portion	Long-Term Debt – Current Portion	400,000		400,000		Long-Term Debt – Current Portion	80,000		80,000
Accounts Payable	Accounts Payable	353,625		490,915		Accounts Payable	514,504		559,676
Accounts Payable to Affiliated Companies	Accounts Payable to Affiliated Companies	100,487		129,575		Accounts Payable to Affiliated Companies	164,953		108,907
Obligations to Third Party Suppliers	Obligations to Third Party Suppliers	125,800		116,273		Obligations to Third Party Suppliers	156,717		142,628
Renewable Portfolio Standards Compliance Obligations	Renewable Portfolio Standards Compliance Obligations	59,387		100,200		Renewable Portfolio Standards Compliance Obligations	157,580		120,239
Regulatory Liabilities	Regulatory Liabilities	274,139		228,248		Regulatory Liabilities	375,047		373,221
Other Current Liabilities	Other Current Liabilities	57,366		84,303		Other Current Liabilities	80,908		83,925
Total Current Liabilities	Total Current Liabilities	1,437,004		1,712,014		Total Current Liabilities	1,677,209		1,468,596
Deferred Credits and Other Liabilities:	Deferred Credits and Other Liabilities:					Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	Accumulated Deferred Income Taxes	1,645,526		1,579,508		Accumulated Deferred Income Taxes	1,758,232		1,700,875
Regulatory Liabilities	Regulatory Liabilities	1,571,705		1,559,072		Regulatory Liabilities	1,557,614		1,548,081

Other Long-Term Liabilities	Other Long-Term Liabilities	276,267		347,934		Other Long-Term Liabilities	292,953		289,313
Total Deferred Credits and Other Liabilities	Total Deferred Credits and Other Liabilities	3,493,498		3,486,514		Total Deferred Credits and Other Liabilities	3,608,799		3,538,269
Long-Term Debt	Long-Term Debt	4,029,660		3,585,399		Long-Term Debt	4,346,024		4,345,085
Preferred Stock Not Subject to Mandatory Redemption	Preferred Stock Not Subject to Mandatory Redemption	43,000		43,000		Preferred Stock Not Subject to Mandatory Redemption	43,000		43,000
Common Stockholder's Equity:	Common Stockholder's Equity:					Common Stockholder's Equity:
Common Stock	Common Stock	—		—		Common Stock	—		—
Capital Surplus, Paid In	Capital Surplus, Paid In	2,303,942		2,253,942		Capital Surplus, Paid In	2,810,242		2,778,942
Retained Earnings	Retained Earnings	2,785,972		2,718,576		Retained Earnings	2,727,367		2,921,444
Accumulated Other Comprehensive Income	Accumulated Other Comprehensive Income	427		501		Accumulated Other Comprehensive Income	268		284
Common Stockholder's Equity	Common Stockholder's Equity	5,090,341		4,973,019		Common Stockholder's Equity	5,537,877		5,700,670
Commitments and Contingencies (Note 9)	Commitments and Contingencies (Note 9)	0		0		Commitments and Contingencies (Note 9)
Total Liabilities and Capitalization	Total Liabilities and Capitalization	$	14,093,503	$	13,799,946	Total Liabilities and Capitalization	$	15,212,909	$	15,095,620

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


		For the Three Months Ended June 30,				For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		2022		2021		(Thousands of Dollars)		2023		2022

Operating Revenues	Operating Revenues	$	783,650	$	687,375	$	1,646,825	$	1,424,418	Operating Revenues		$	956,283	$	863,176

Operating Expenses:	Operating Expenses:									Operating Expenses:
Purchased Power and Transmission	Purchased Power and Transmission	236,789		191,137		550,537		417,615		Purchased Power and Transmission		360,925		313,748
Operations and Maintenance	Operations and Maintenance	149,094		136,356		313,956		279,576		Operations and Maintenance		166,083		164,862
Depreciation	Depreciation	89,701		83,917		178,734		166,710		Depreciation		90,430		89,033
Amortization of Regulatory Assets/(Liabilities), Net		20,022		(2,528)		49,367		15,890
Amortization of Regulatory Assets, Net										Amortization of Regulatory Assets, Net		22,785		29,345
Energy Efficiency Programs	Energy Efficiency Programs	69,290		64,273		149,522		139,373		Energy Efficiency Programs		86,217		80,232
Taxes Other Than Income Taxes	Taxes Other Than Income Taxes	60,891		54,126		120,664		108,776		Taxes Other Than Income Taxes		53,510		59,774
Total Operating Expenses	Total Operating Expenses	625,787		527,281		1,362,780		1,127,940		Total Operating Expenses		779,950		736,994
Operating Income	Operating Income	157,863		160,094		284,045		296,478		Operating Income		176,333		126,182
Interest Expense	Interest Expense	38,984		37,195		77,206		69,501		Interest Expense		44,865		38,222
Other Income, Net	Other Income, Net	34,259		21,915		63,490		38,727		Other Income, Net		39,873		29,231
Income Before Income Tax Expense	Income Before Income Tax Expense	153,138		144,814		270,329		265,704		Income Before Income Tax Expense		171,341		117,191
Income Tax Expense	Income Tax Expense	33,701		33,902		58,152		60,868		Income Tax Expense		37,528		24,452
Net Income	Net Income	$	119,437	$	110,912	$	212,177	$	204,836	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 June 30,				For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		2022		2021		(Thousands of Dollars)		2023		2022

Net Income	Net Income	$	119,437	$	110,912	$	212,177	$	204,836	Net Income		$	133,813	$	92,739
Other Comprehensive (Loss)/Income, Net of Tax:
Other Comprehensive Loss, Net of Tax:										Other Comprehensive Loss, Net of Tax:
Changes in Funded Status of SERP Benefit Plan	Changes in Funded Status of SERP Benefit Plan	(27)		(40)		(72)		(81)		Changes in Funded Status of SERP Benefit Plan		(33)		(44)
Qualified Cash Flow Hedging Instruments	Qualified Cash Flow Hedging Instruments	5		179		10		288		Qualified Cash Flow Hedging Instruments		5		5
Changes in Unrealized (Losses)/Gains on Marketable Securities		(5)		2		(12)		(5)
Other Comprehensive (Loss)/Income, Net of Tax		(27)		141		(74)		202
Changes in Unrealized Gains/(Losses) on Marketable Securities										Changes in Unrealized Gains/(Losses) on Marketable Securities		12		(8)
Other Comprehensive Loss, Net of Tax										Other Comprehensive Loss, Net of Tax		(16)		(47)
Comprehensive Income	Comprehensive Income	$	119,410	$	111,053	$	212,103	$	205,038	Comprehensive Income		$	133,797	$	92,692

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

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)


		For the Six Months Ended June 30, 2022																			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				Common Stock					Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Income			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	(Thousands of Dollars, Except Stock Information)	Stock	Amount								(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
Balance as of January 1, 2023																				Balance as of January 1, 2023	200			$	—		$	2,778,942		$	2,921,444		$	284		$	5,700,670
Net Income	Net Income								119,437								119,437			Net Income									133,813						133,813
Dividends on Preferred Stock	Dividends on Preferred Stock								(490)								(490)			Dividends on Preferred Stock									(490)						(490)
Dividends on Common Stock	Dividends on Common Stock								(71,900)								(71,900)			Dividends on Common Stock									(327,400)						(327,400)
Capital Contributions from Eversource Parent	Capital Contributions from Eversource Parent				50,000												50,000			Capital Contributions from Eversource Parent						31,300									31,300
Other Comprehensive Loss	Other Comprehensive Loss												(27)				(27)			Other Comprehensive Loss												(16)			(16)
Balance as of June 30, 2022		200	$	—	$	2,303,942			$	2,785,972			$	427			$	5,090,341
Balance as of March 31, 2023																				Balance as of March 31, 2023	200			$	—	$	2,810,242		$	2,727,367		$	268		$	5,537,877


		For the Six Months Ended June 30, 2021																			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				Common Stock					Capital Surplus, Paid In			Retained Earnings			Accumulated Other Comprehensive Income			Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information)	(Thousands of Dollars, Except Stock Information)	Stock	Amount								(Thousands of Dollars, Except Stock Information)	Stock								Amount
Balance as of January 1, 2021		200	$	—			$	1,993,942							$	2,527,167			$	309		$	4,521,418
Balance as of January 1, 2022																				Balance as of January 1, 2022	200			$	—		$	2,253,942		$	2,718,576		$	501		$	4,973,019
Net Income	Net Income								93,924								93,924			Net Income									92,739						92,739
Dividends on Preferred Stock	Dividends on Preferred Stock								(490)								(490)			Dividends on Preferred Stock									(490)						(490)
Dividends on Common Stock	Dividends on Common Stock								(206,400)								(206,400)			Dividends on Common Stock									(71,900)						(71,900)
Other Comprehensive Income													61				61
Balance as of March 31, 2021		200	—		1,993,942				2,414,201				370				4,408,513
Net Income									110,912								110,912
Dividends on Preferred Stock									(490)								(490)
Dividends on Common Stock									(76,800)								(76,800)
Capital Contributions from Eversource Parent					60,000												60,000
Other Comprehensive Income													141				141
Balance as of June 30, 2021		200	$	—	$	2,053,942			$	2,447,823			$	511			$	4,502,276
Other Comprehensive Loss																				Other Comprehensive Loss												(47)			(47)
Balance as of March 31, 2022																				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.

NSTAR ELECTRIC COMPANY AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


		For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		(Thousands of Dollars)	2023		2022

Operating Activities:	Operating Activities:					Operating Activities:
Net Income	Net Income	$	212,177	$	204,836	Net Income	$	133,813	$	92,739
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:	Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:					Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Depreciation	Depreciation	178,734		166,710		Depreciation	90,430		89,033
Deferred Income Taxes	Deferred Income Taxes	42,476		28,742		Deferred Income Taxes	44,403		26,857
Uncollectible Expense	Uncollectible Expense	8,688		7,394		Uncollectible Expense	4,697		4,662
Pension, SERP and PBOP Income, Net	Pension, SERP and PBOP Income, Net	(27,750)		(12,990)		Pension, SERP and PBOP Income, Net	(9,886)		(13,742)
Pension Contributions	Pension Contributions	(10,000)		(10,000)		Pension Contributions	—		(5,000)
Regulatory Underrecoveries, Net		(106,074)		(12,562)
Regulatory Under Recoveries, Net						Regulatory Under Recoveries, Net	(58,000)		(10,813)
Amortization of Regulatory Assets, Net	Amortization of Regulatory Assets, Net	49,367		15,890		Amortization of Regulatory Assets, Net	22,785		29,345
Cost of Removal Expenditures	Cost of Removal Expenditures	(26,337)		(26,968)		Cost of Removal Expenditures	(12,893)		(12,852)
Payment of Withheld Property Taxes		(76,084)		—

Other	Other	(24,635)		(13,347)		Other	(9,921)		(5,531)
Changes in Current Assets and Liabilities:	Changes in Current Assets and Liabilities:					Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	Receivables and Unbilled Revenues, Net	35,107		(49,324)		Receivables and Unbilled Revenues, Net	(90,684)		2,051

Taxes Receivable/Accrued, Net	Taxes Receivable/Accrued, Net	58,289		57,584		Taxes Receivable/Accrued, Net	11,977		45,299
Accounts Payable	Accounts Payable	(98,187)		(88,729)		Accounts Payable	20,249		(55,743)
Other Current Assets and Liabilities, Net	Other Current Assets and Liabilities, Net	(18,644)		(21,349)		Other Current Assets and Liabilities, Net	(6,185)		3,559
Net Cash Flows Provided by Operating Activities	Net Cash Flows Provided by Operating Activities	197,127		245,887		Net Cash Flows Provided by Operating Activities	140,785		189,864

Investing Activities:	Investing Activities:					Investing Activities:
Investments in Property, Plant and Equipment	Investments in Property, Plant and Equipment	(443,978)		(426,053)		Investments in Property, Plant and Equipment	(318,673)		(234,120)
Other Investing Activities	Other Investing Activities	118		43		Other Investing Activities	35		96
Net Cash Flows Used in Investing Activities	Net Cash Flows Used in Investing Activities	(443,860)		(426,010)		Net Cash Flows Used in Investing Activities	(318,638)		(234,024)

Financing Activities:	Financing Activities:					Financing Activities:
Cash Dividends on Common Stock	Cash Dividends on Common Stock	(143,800)		(283,200)		Cash Dividends on Common Stock	(327,400)		(71,900)
Cash Dividends on Preferred Stock	Cash Dividends on Preferred Stock	(980)		(980)		Cash Dividends on Preferred Stock	(490)		(490)
Issuance of Long-Term Debt		450,000		300,000
Retirement of Long-Term Debt		—		(250,000)

Capital Contributions from Eversource Parent	Capital Contributions from Eversource Parent	50,000		60,000		Capital Contributions from Eversource Parent	31,300		—
Increase in Notes Payable to Eversource Parent	Increase in Notes Payable to Eversource Parent	3,200		200		Increase in Notes Payable to Eversource Parent	—		4,000
(Decrease)/Increase in Notes Payable		(99,500)		360,500
Increase in Notes Payable						Increase in Notes Payable	147,500		112,500
Other Financing Activities	Other Financing Activities	(7,642)		(5,909)		Other Financing Activities	5		15
Net Cash Flows Provided by Financing Activities		251,278		180,611
Net Increase in Cash and Restricted Cash		4,545		488
Cash and Restricted Cash - Beginning of Period		18,179		17,410
Net Cash Flows (Used in)/Provided by Financing Activities						Net Cash Flows (Used in)/Provided by Financing Activities	(149,085)		44,125
Net Decrease in Cash, Cash Equivalents and Restricted Cash						Net Decrease in Cash, Cash Equivalents and Restricted Cash	(326,938)		(35)
Cash, Cash Equivalents and Restricted Cash - Beginning of Period						Cash, Cash Equivalents and Restricted Cash - Beginning of Period	345,293		18,179
Cash and Restricted Cash - End of Period	Cash and Restricted Cash - End of Period	$	22,724	$	17,898	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.

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)


(Thousands of Dollars)	(Thousands of Dollars)	As of June 30, 2022		As of December 31, 2021		(Thousands of Dollars)	As of March 31, 2023		As of December 31, 2022

ASSETS	ASSETS					ASSETS
Current Assets:	Current Assets:					Current Assets:
Cash	Cash	$	133	$	15	Cash	$	88	$	136
Receivables, Net (net of allowance for uncollectible accounts of $27,314 and $24,331 as of June 30, 2022 and December 31, 2021, respectively)		151,444		124,232
Receivables, Net (net of allowance for uncollectible accounts of $33,505 and $29,236 as of March 31, 2023 and December 31, 2022, respectively)						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	Accounts Receivable from Affiliated Companies	7,792		17,156		Accounts Receivable from Affiliated Companies	25,270		8,193
Unbilled Revenues	Unbilled Revenues	48,161		53,937		Unbilled Revenues	67,266		72,713

Taxes Receivable						Taxes Receivable	48,173		27,978
Materials, Supplies and REC Inventory	Materials, Supplies and REC Inventory	40,810		25,930		Materials, Supplies and REC Inventory	43,492		34,521
Regulatory Assets	Regulatory Assets	93,225		107,169		Regulatory Assets	140,912		102,240
Special Deposits	Special Deposits	30,935		31,390		Special Deposits	19,469		33,140

Prepayments and Other Current Assets	Prepayments and Other Current Assets	24,592		22,109		Prepayments and Other Current Assets	6,869		13,297
Total Current Assets	Total Current Assets	397,092		381,938		Total Current Assets	519,499		465,555
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net	3,820,237		3,656,462		Property, Plant and Equipment, Net	4,147,985		4,060,224
Deferred Debits and Other Assets:	Deferred Debits and Other Assets:					Deferred Debits and Other Assets:
Regulatory Assets	Regulatory Assets	643,745		679,182		Regulatory Assets	697,568		593,974
Prepaid Pension						Prepaid Pension	70,892		66,384
Other Long-Term Assets	Other Long-Term Assets	19,797		23,202		Other Long-Term Assets	15,183		16,517
Total Deferred Debits and Other Assets	Total Deferred Debits and Other Assets	663,542		702,384		Total Deferred Debits and Other Assets	783,643		676,875
Total Assets	Total Assets	$	4,880,871	$	4,740,784	Total Assets	$	5,451,127	$	5,202,654

LIABILITIES AND CAPITALIZATION	LIABILITIES AND CAPITALIZATION					LIABILITIES AND CAPITALIZATION
Current Liabilities:	Current Liabilities:					Current Liabilities:
Notes Payable to Eversource Parent	Notes Payable to Eversource Parent	$	89,300	$	110,600	Notes Payable to Eversource Parent	$	121,100	$	173,300

Long-Term Debt – Current Portion						Long-Term Debt – Current Portion	325,000		29,668
Rate Reduction Bonds – Current Portion	Rate Reduction Bonds – Current Portion	43,210		43,210		Rate Reduction Bonds – Current Portion	43,210		43,210
Accounts Payable	Accounts Payable	179,824		166,452		Accounts Payable	301,547		291,556
Accounts Payable to Affiliated Companies	Accounts Payable to Affiliated Companies	26,994		43,485		Accounts Payable to Affiliated Companies	51,985		36,231
Regulatory Liabilities	Regulatory Liabilities	106,554		120,176		Regulatory Liabilities	86,569		161,963

Other Current Liabilities	Other Current Liabilities	54,772		63,005		Other Current Liabilities	62,784		59,616
Total Current Liabilities	Total Current Liabilities	500,654		546,928		Total Current Liabilities	992,195		795,544
Deferred Credits and Other Liabilities:	Deferred Credits and Other Liabilities:					Deferred Credits and Other Liabilities:
Accumulated Deferred Income Taxes	Accumulated Deferred Income Taxes	543,771		537,978		Accumulated Deferred Income Taxes	625,374		562,802
Regulatory Liabilities	Regulatory Liabilities	393,673		381,366		Regulatory Liabilities	390,290		391,628

Other Long-Term Liabilities	Other Long-Term Liabilities	43,188		64,264		Other Long-Term Liabilities	37,418		37,087
Total Deferred Credits and Other Liabilities	Total Deferred Credits and Other Liabilities	980,632		983,608		Total Deferred Credits and Other Liabilities	1,053,082		991,517
Long-Term Debt	Long-Term Debt	1,164,229		1,163,833		Long-Term Debt	1,134,407		1,134,914
Rate Reduction Bonds	Rate Reduction Bonds	432,097		453,702		Rate Reduction Bonds	388,887		410,492
Common Stockholder's Equity:	Common Stockholder's Equity:					Common Stockholder's Equity:
Common Stock	Common Stock	—		—		Common Stock	—		—
Capital Surplus, Paid In	Capital Surplus, Paid In	1,268,134		1,088,134		Capital Surplus, Paid In	1,298,134		1,298,134
Retained Earnings	Retained Earnings	535,180		504,556		Retained Earnings	584,422		572,126
Accumulated Other Comprehensive (Loss)/Income		(55)		23
Accumulated Other Comprehensive Loss						Accumulated Other Comprehensive Loss	—		(73)
Common Stockholder's Equity	Common Stockholder's Equity	1,803,259		1,592,713		Common Stockholder's Equity	1,882,556		1,870,187
Commitments and Contingencies (Note 9)	Commitments and Contingencies (Note 9)	0		0		Commitments and Contingencies (Note 9)
Total Liabilities and Capitalization	Total Liabilities and Capitalization	$	4,880,871	$	4,740,784	Total Liabilities and Capitalization	$	5,451,127	$	5,202,654

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

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)


		For the Three Months Ended June 30,				For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		2022		2021		(Thousands of Dollars)		2023		2022

Operating Revenues	Operating Revenues	$	307,055	$	278,849	$	646,482	$	572,284	Operating Revenues		$	420,155	$	339,427

Operating Expenses:	Operating Expenses:									Operating Expenses:
Purchased Power and Transmission	Purchased Power and Transmission	110,803		80,513		236,647		172,122		Purchased Power and Transmission		226,685		125,844
Operations and Maintenance	Operations and Maintenance	66,730		56,537		126,303		111,201		Operations and Maintenance		67,796		59,573
Depreciation	Depreciation	31,557		29,825		62,810		59,293		Depreciation		34,088		31,253
Amortization of Regulatory Assets, Net		9,218		26,274		36,052		44,821
Amortization of Regulatory (Liabilities)/Assets, Net										Amortization of Regulatory (Liabilities)/Assets, Net		(5,317)		26,834
Energy Efficiency Programs	Energy Efficiency Programs	8,817		9,365		17,535		19,713		Energy Efficiency Programs		10,226		8,718
Taxes Other Than Income Taxes	Taxes Other Than Income Taxes	25,261		23,453		48,046		45,603		Taxes Other Than Income Taxes		22,105		22,785
Total Operating Expenses	Total Operating Expenses	252,386		225,967		527,393		452,753		Total Operating Expenses		355,583		275,007
Operating Income	Operating Income	54,669		52,882		119,089		119,531		Operating Income		64,572		64,420
Interest Expense	Interest Expense	14,757		13,821		28,402		28,452		Interest Expense		17,542		13,645
Other Income, Net	Other Income, Net	7,782		4,260		15,292		8,427		Other Income, Net		5,717		7,509
Income Before Income Tax Expense	Income Before Income Tax Expense	47,694		43,321		105,979		99,506		Income Before Income Tax Expense		52,747		58,284
Income Tax Expense	Income Tax Expense	10,656		8,688		23,355		20,197		Income Tax Expense		12,451		12,698
Net Income	Net Income	$	37,038	$	34,633	$	82,624	$	79,309	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 June 30, For the Six Months Ended June 30,
(Thousands of Dollars) 2022 2021 2022 2021
Net Income $ 37,038 $ 34,633 $ 82,624 $ 79,309
Other Comprehensive (Loss)/Income, Net of Tax:
Qualified Cash Flow Hedging Instruments — 266 — 564
Changes in Unrealized (Losses)/Gains on
Marketable Securities (30) 16 (78) (27)
Other Comprehensive (Loss)/Income, Net of Tax (30) 282 (78) 537
Comprehensive Income $ 37,008 $ 34,915 $ 82,546 $ 79,846


	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.

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY

(Unaudited)

For the Six Months Ended June 30, 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
Net Income 37,038 37,038
Dividends on Common Stock (26,000) (26,000)
Capital Contributions from Eversource Parent 180,000 180,000
Other Comprehensive Loss (30) (30)
Balance as of June 30, 2022 301 $ — $ 1,268,134 $ 535,180 $ (55) $ 1,803,259


	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 Six Months Ended June 30, 2021
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, 2021 301 $ — $ 928,134 $ 615,018 $ (613) $ 1,542,539
Net Income 44,676 44,676
Dividends on Common Stock (25,200) (25,200)
Other Comprehensive Income 255 255
Balance as of March 31, 2021 301 — 928,134 634,494 (358) 1,562,270
Net Income 34,633 34,633
Dividends on Common Stock (185,200) (185,200)
Capital Contributions from Eversource Parent 160,000 160,000
Other Comprehensive Income 282 282
Balance as of June 30, 2021 301 $ — $ 1,088,134 $ 483,927 $ (76) $ 1,571,985


	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.

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


		For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Thousands of Dollars)	(Thousands of Dollars)	2022		2021		(Thousands of Dollars)	2023		2022

Operating Activities:	Operating Activities:					Operating Activities:
Net Income	Net Income	$	82,624	$	79,309	Net Income	$	40,296	$	45,586
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities:
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:						Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities:
Depreciation	Depreciation	62,810		59,293		Depreciation	34,088		31,253
Deferred Income Taxes	Deferred Income Taxes	3,137		(842)		Deferred Income Taxes	62,924		7,480
Uncollectible Expense	Uncollectible Expense	4,544		3,226		Uncollectible Expense	5,060		2,496
Pension, SERP and PBOP Income, Net	Pension, SERP and PBOP Income, Net	(8,118)		(1,868)		Pension, SERP and PBOP Income, Net	(2,552)		(3,997)
Regulatory Underrecoveries, Net		(1,744)		(6,965)
Amortization of Regulatory Assets, Net		36,052		44,821
Regulatory Under Recoveries, Net						Regulatory Under Recoveries, Net	(175,865)		(32,186)
Amortization of Regulatory (Liabilities)/Assets, Net						Amortization of Regulatory (Liabilities)/Assets, Net	(5,317)		26,834

Cost of Removal Expenditures	Cost of Removal Expenditures	(16,560)		(13,164)		Cost of Removal Expenditures	(4,508)		(7,131)
Other	Other	4,436		587		Other	1,711		(4,631)
Changes in Current Assets and Liabilities:	Changes in Current Assets and Liabilities:					Changes in Current Assets and Liabilities:
Receivables and Unbilled Revenues, Net	Receivables and Unbilled Revenues, Net	(17,306)		(3,717)		Receivables and Unbilled Revenues, Net	(21,230)		(25,972)

Taxes Receivable/Accrued, Net	Taxes Receivable/Accrued, Net	10,138		9,183		Taxes Receivable/Accrued, Net	(20,195)		8,067
Accounts Payable	Accounts Payable	15,920		(29,320)		Accounts Payable	10,265		9,389
Other Current Assets and Liabilities, Net	Other Current Assets and Liabilities, Net	(35,559)		(2,240)		Other Current Assets and Liabilities, Net	2,462		895
Net Cash Flows Provided by Operating Activities		140,374		138,303
Net Cash Flows (Used In)/Provided by Operating Activities						Net Cash Flows (Used In)/Provided by Operating Activities	(72,861)		58,083

Investing Activities:	Investing Activities:					Investing Activities:
Investments in Property, Plant and Equipment	Investments in Property, Plant and Equipment	(226,975)		(134,256)		Investments in Property, Plant and Equipment	(133,890)		(107,916)
Other Investing Activities	Other Investing Activities	726		270		Other Investing Activities	216		593
Net Cash Flows Used in Investing Activities	Net Cash Flows Used in Investing Activities	(226,249)		(133,986)		Net Cash Flows Used in Investing Activities	(133,674)		(107,323)

Financing Activities:	Financing Activities:					Financing Activities:
Cash Dividends on Common Stock	Cash Dividends on Common Stock	(52,000)		(210,400)		Cash Dividends on Common Stock	(28,000)		(26,000)
Capital Contributions from Eversource Parent		180,000		160,000

Issuance of Long-Term Debt	Issuance of Long-Term Debt	—		350,000		Issuance of Long-Term Debt	300,000		—
Retirement of Long-Term Debt		—		(282,000)

Repayment of Rate Reduction Bonds	Repayment of Rate Reduction Bonds	(21,605)		(21,605)		Repayment of Rate Reduction Bonds	(21,605)		(21,605)
(Decrease)/Increase in Notes Payable to Eversource Parent	(Decrease)/Increase in Notes Payable to Eversource Parent	(21,300)		2,300		(Decrease)/Increase in Notes Payable to Eversource Parent	(52,200)		85,800
Other Financing Activities	Other Financing Activities	(47)		(2,941)		Other Financing Activities	(5,460)		(23)
Net Cash Flows Provided by/(Used in) Financing Activities		85,048		(4,646)
Net Cash Flows Provided by Financing Activities						Net Cash Flows Provided by Financing Activities	192,735		38,172
Net Decrease in Cash and Restricted Cash	Net Decrease in Cash and Restricted Cash	(827)		(329)		Net Decrease in Cash and Restricted Cash	(13,800)		(11,068)
Cash and Restricted Cash - Beginning of Period	Cash and Restricted Cash - Beginning of Period	35,126		39,555		Cash and Restricted Cash - Beginning of Period	36,812		35,126
Cash and Restricted Cash - End of Period	Cash and Restricted Cash - End of Period	$	34,299	$	39,226	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.

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 ~~Eversource Gas Company of Massachusetts (EGMA)~~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 10twelve 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 ~~2021~~2022 Form 10-K, which was filed with the SEC on February ~~17, 2022.~~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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~2022, and the results of operations, comprehensive income, ~~and~~ common shareholders' equity ~~for the three~~ and ~~six months ended June 30, 2022 and 2021 and the~~ cash flows for the ~~six~~three months ended ~~June 30, 2022~~March 31, 2023 and ~~2021.~~2022. The results of operations, ~~and~~ comprehensive income ~~for the three~~ and ~~six months ended June 30, 2022 and 2021 and the~~ cash flows for the ~~six~~three months ended ~~June 30,~~March 31, 2023 and 2022 ~~and 2021~~ 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).

~~Receivables are presented net of expected credit losses at estimated net realizable value by maintaining an 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 ~~June 30, 2022~~March 31, 2023 adequately reflected the collection risk and net realizable value for its receivables.

As of ~~June 30, 2022~~both March 31, 2023 and December 31, ~~2021,~~2022, the total amount incurred as a result of COVID-19 included in the allowance for uncollectible accounts was ~~$63.1 million and $55.3~~$50.9 million at Eversource, ~~$20.4 million and $23.9~~$16.0 million at CL&P, and ~~$7.5 million and $9.0~~$4.1 million at NSTAR ~~Electric, respectively.~~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 ~~June 30~~March 31thst is as follows:


		Eversource						CL&P						NSTAR Electric						PSNH			Eversource						CL&P						NSTAR Electric						PSNH
(Millions of Dollars)	(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		(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 2022

Three Months Ended 2023																						Three Months Ended 2023
Beginning Balance	Beginning Balance	$	225.5	$	206.7	$	432.2	$	140.1	$	40.4	$	180.5	$	39.7	$	55.1	$	94.8	$	26.2	Beginning Balance	$	284.4	$	201.9	$	486.3	$	188.9	$	36.4	$	225.3	$	43.7	$	51.3	$	95.0	$	29.2
Uncollectible Expense	Uncollectible Expense	—		12.9		12.9		—		2.9		2.9		—		4.0		4.0		2.0		Uncollectible Expense	—		22.8		22.8		—		3.9		3.9		—		4.7		4.7		5.1
Uncollectible Costs Deferred (1)	Uncollectible Costs Deferred (1)	21.4		12.6		34.0		15.0		2.2		17.2		5.4		2.4		7.8		0.1		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	Write-Offs	(4.6)		(21.1)		(25.7)		(3.3)		(6.2)		(9.5)		(0.1)		(7.7)		(7.8)		(1.3)		Write-Offs	(9.7)		(26.3)		(36.0)		(7.3)		(7.0)		(14.3)		(0.4)		(10.3)		(10.7)		(2.2)
Recoveries Collected	Recoveries Collected	0.4		4.0		4.4		0.3		1.3		1.6		—		1.7		1.7		0.3		Recoveries Collected	0.3		3.7		4.0		0.3		1.2		1.5		—		1.5		1.5		0.2
Ending Balance	Ending Balance	$	242.7	$	215.1	$	457.8	$	152.1	$	40.6	$	192.7	$	45.0	$	55.5	$	100.5	$	27.3	Ending Balance	$	318.7	$	216.4	$	535.1	$	216.2	$	37.2	$	253.4	$	42.0	$	52.6	$	94.6	$	33.5

Six 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		—		30.0		30.0		—		6.7		6.7		—		8.7		8.7		4.5
Uncollectible Costs Deferred (1)		22.4		27.3		49.7		11.0		—		11.0		2.1		7.8		9.9		1.1
Write-Offs		(6.9)		(43.1)		(50.0)		(4.4)		(6.7)		(11.1)		(0.4)		(18.3)		(18.7)		(3.1)
Recoveries Collected		1.1		9.6		10.7		0.9		3.9		4.8		—		3.6		3.6		0.5
Ending Balance		$	242.7	$	215.1	$	457.8	$	152.1	$	40.6	$	192.7	$	45.0	$	55.5	$	100.5	$	27.3


		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 2021

Three Months Ended 2022																						Three Months Ended 2022
Beginning Balance	Beginning Balance	$	197.3	$	194.4	$	391.7	$	138.4	$	36.7	$	175.1	$	31.1	$	58.2	$	89.3	$	17.3	Beginning Balance	$	226.1	$	191.3	$	417.4	$	144.6	$	36.7	$	181.3	$	43.3	$	53.7	$	97.0	$	24.3
Uncollectible Expense	Uncollectible Expense	—		11.4		11.4		—		2.8		2.8		—		3.5		3.5		2.0		Uncollectible Expense	—		17.1		17.1		—		3.8		3.8		—		4.7		4.7		2.5
Uncollectible Costs Deferred (1)	Uncollectible Costs Deferred (1)	16.6		24.5		41.1		9.3		8.3		17.6		4.9		6.9		11.8		(0.3)		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	Write-Offs	(3.4)		(18.1)		(21.5)		(2.3)		(5.4)		(7.7)		(0.1)		(7.7)		(7.8)		(2.0)		Write-Offs	(2.3)		(22.0)		(24.3)		(1.1)		(0.5)		(1.6)		(0.3)		(10.6)		(10.9)		(1.8)
Recoveries Collected	Recoveries Collected	0.2		2.9		3.1		0.2		0.8		1.0		—		1.2		1.2		0.2		Recoveries Collected	0.8		5.5		6.3		0.6		2.5		3.1		—		1.9		1.9		0.2
Ending Balance	Ending Balance	$	210.7	$	215.1	$	425.8	$	145.6	$	43.2	$	188.8	$	35.9	$	62.1	$	98.0	$	17.2	Ending Balance	$	225.5	$	206.7	$	432.2	$	140.1	$	40.4	$	180.5	$	39.7	$	55.1	$	94.8	$	26.2

Six Months Ended 2021
Beginning Balance		$	194.8	$	164.1	$	358.9	$	129.1	$	28.3	$	157.4	$	39.7	$	51.9	$	91.6	$	17.2
Uncollectible Expense		—		27.7		27.7		—		6.6		6.6		—		7.4		7.4		3.2
Uncollectible Costs Deferred (1)		22.0		51.6		73.6		21.2		15.7		36.9		(3.5)		15.2		11.7		0.8
Write-Offs		(6.7)		(34.8)		(41.5)		(5.2)		(9.3)		(14.5)		(0.3)		(15.2)		(15.5)		(4.5)
Recoveries Collected		0.6		6.5		7.1		0.5		1.9		2.4		—		2.8		2.8		0.5
Ending Balance		$	210.7	$	215.1	$	425.8	$	145.6	$	43.2	$	188.8	$	35.9	$	62.1	$	98.0	$	17.2

(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 ~~the~~ marketable securities held in trusts. Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill, long-lived assets, 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
June 30, 2022 June 30, 2021
(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 $ 54.9 $ 16.2 $ 21.4 $ 6.7 $ 22.1 $ 4.3 $ 10.2 $ 2.7
AFUDC Equity 11.2 2.8 6.1 0.6 9.2 1.7 6.2 0.3
Equity in Earnings of Unconsolidated Affiliates (1)
16.6 — 0.1 — 4.7 — 0.1 —
Investment Income/(Loss) 1.3 (0.7) 0.5 0.1 1.9 1.2 0.6 0.3
Interest Income 9.5 1.5 6.1 0.4 8.4 2.7 4.8 0.9
Other 0.4 — 0.1 — 0.3 — — 0.1
Total Other Income, Net $ 93.9 $ 19.8 $ 34.3 $ 7.8 $ 46.6 $ 9.9 $ 21.9 $ 4.3
For the Six Months Ended
June 30, 2022 June 30, 2021
(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 $ 109.2 $ 32.1 $ 42.4 $ 13.3 $ 42.2 $ 7.0 $ 20.2 $ 5.4
AFUDC Equity 21.1 5.6 11.0 1.0 18.4 3.4 12.4 0.9
Equity in Earnings of Unconsolidated Affiliates (1)
17.1 — 0.1 — 8.4 — 0.2 —
Investment Income/(Loss) 1.1 (1.1) 0.2 0.3 1.3 1.5 0.8 0.4
Interest Income 16.1 2.8 9.6 0.7 9.9 2.8 4.9 1.6
Other 0.8 — 0.2 — 0.6 0.1 0.2 0.1
Total Other Income, Net $ 165.4 $ 39.4 $ 63.5 $ 15.3 $ 80.8 $ 14.8 $ 38.7 $ 8.4

~~(1)~~ Equity in earnings of unconsolidated affiliates includes $12.2 million of pre-tax unrealized gains associated with an investment in a renewable energy fund for the three and six months ended June 30, 2022. For the three and six months ended June 30, 2021, equity in earnings of unconsolidated affiliates included $2.1 million of pre-tax unrealized gains associated with this investment.














	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)	(Millions of Dollars)	Ownership Interest		As of June 30, 2022		As of December 31, 2021		(Millions of Dollars)	Ownership Interest		As of March 31, 2023		As of December 31, 2022
Offshore Wind Business - North East Offshore	Offshore Wind Business - North East Offshore	50	%	$	1,487.1	$	1,213.6	Offshore Wind Business - North East Offshore	50	%	$	2,159.2	$	1,947.1
Natural Gas Pipeline - Algonquin Gas Transmission, LLC	Natural Gas Pipeline - Algonquin Gas Transmission, LLC	15	%	119.3		121.9		Natural Gas Pipeline - Algonquin Gas Transmission, LLC	15	%	117.5		118.8
Renewable Energy Investment Fund	Renewable Energy Investment Fund	90	%	88.4		76.5		Renewable Energy Investment Fund	90	%	—		84.1
Other	Other	various		25.1		24.3		Other	various		26.2		26.1
Total Investments in Unconsolidated Affiliates	Total Investments in Unconsolidated Affiliates			$	1,719.9	$	1,436.3	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. ~~Cash flows used in investing activities presented in Investments in Unconsolidated Affiliates, Net on the statements of cash flows relates to capital contributions in the offshore wind investment.~~

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 ~~has advanced its strategic review~~continues to work with interested parties through this ongoing process and is working with its advisors on the outreach strategy and marketing materials, which will aid the Company in evaluating the alternatives available for its wind investment. In late July, Eversource started preliminary and targeted outreach to potential buyers. Eversource expects to complete this review ~~during 2022.~~in the second quarter of 2023. Eversource’s strategic review of its offshore wind investment does not impact the ~~June 30, 2022~~presentation of the March 31, 2023 financial statements.

F.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				For the Six Months Ended					For the Three Months Ended
(Millions of Dollars)	(Millions of Dollars)	June 30, 2022		June 30, 2021		June 30, 2022		June 30, 2021		(Millions of Dollars)		March 31, 2023		March 31, 2022
Eversource	Eversource	$	44.5	$	39.9	$	93.1	$	88.5	Eversource		$	55.0	$	48.6
CL&P	CL&P	39.0		35.4		76.8		74.6		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)	(Millions of Dollars)	As of June 30, 2022		As of June 30, 2021		(Millions of Dollars)	As of March 31, 2023		As of March 31, 2022
Eversource	Eversource	$	357.2	$	344.8	Eversource	$	400.8	$	385.6
CL&P	CL&P	96.7		66.4		CL&P	101.9		102.1
NSTAR Electric	NSTAR Electric	75.1		103.8		NSTAR Electric	117.4		85.8
PSNH	PSNH	49.6		33.9		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 June 30, 2022								As of December 31, 2021									As of March 31, 2023								As of December 31, 2022
(Millions of Dollars)	(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Cash as reported on the Balance Sheets		$	29.5	$	9.2	$	5.3	$	0.1	$	66.8	$	55.8	$	0.7	$	—
Cash and Cash Equivalents as reported on the Balance Sheets																		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:	Restricted cash included in:																	Restricted cash included in:
Special Deposits	Special Deposits	90.8		8.7		17.4		30.9		78.2		18.7		17.4		31.4		Special Deposits	89.0		8.9		17.8		19.5		102.2		8.8		17.5		33.1
Marketable Securities	Marketable Securities	17.2		—		—		0.1		31.3		0.3		0.1		0.5		Marketable Securities	17.9		0.2		—		0.2		25.4		0.2		0.1		0.4
Other Long-Term Assets	Other Long-Term Assets	19.2		—		—		3.2		44.7		—		—		3.2		Other Long-Term Assets	19.9		—		—		3.2		19.6		—		—		3.2
Cash and Restricted Cash as reported on the Statements of Cash Flows		$	156.7	$	17.9	$	22.7	$	34.3	$	221.0	$	74.8	$	18.2	$	35.1
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows																		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. The December 31, 2021 balance also included a $10 million customer assistance fund to provide bill payment assistance to certain existing non-hardship and hardship customers carrying arrearages at CL&P established under the terms of the PURA-approved October 2021 settlement agreement. Those customers were provided with $10 million of bill forgiveness in the first quarter of 2022, which represented a non-cash transaction. 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 ~~also~~ 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. ~~As of June 30, 2022,~~This restricted cash included $20.0 million ~~of this restricted cash was~~ 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 ~~was recorded in Other Long-Term Assets. As of December 31, 2021, this restricted cash totaled $41.5 million and was~~ recorded in Other Long-Term Assets on the balance ~~sheet.~~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 June 30, 2022								As of December 31, 2021									As of March 31, 2023								As of December 31, 2022
(Millions of Dollars)	(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH
Benefit Costs		$	1,435.0	$	267.6	$	397.2	$	116.7	$	1,481.0	$	272.4	$	395.5	$	118.9
Storm Costs, Net	Storm Costs, Net	1,250.1		733.8		455.0		61.3		1,102.7		695.6		341.3		65.8		Storm Costs, Net	$	1,658.7	$	889.2	$	564.9	$	204.6	$	1,379.1	$	799.3	$	484.4	$	95.4
Regulatory Tracking Mechanisms	Regulatory Tracking Mechanisms	979.0		306.1		368.7		68.3		1,050.5		333.6		376.6		85.4		Regulatory Tracking Mechanisms	1,028.7		228.2		432.4		122.8		1,075.3		216.8		391.5		73.7
Benefit Costs																		Benefit Costs	910.3		155.6		294.4		56.1		921.7		156.7		299.5		56.6
Income Taxes, Net	Income Taxes, Net	798.0		476.6		113.6		13.9		790.7		470.5		112.6		17.5		Income Taxes, Net	856.1		492.9		118.1		13.1		853.3		491.1		115.6		16.0
Securitized Stranded Costs	Securitized Stranded Costs	457.3		—		—		457.3		478.9		—		—		478.9		Securitized Stranded Costs	424.9		—		—		424.9		435.7		—		—		435.7
Goodwill-related	Goodwill-related	289.4		—		248.4		—		297.8		—		255.7		—		Goodwill-related	276.7		—		237.6		—		281.0		—		241.2		—
Derivative Liabilities	Derivative Liabilities	213.3		213.3		—		—		249.2		249.2		—		—		Derivative Liabilities	168.8		168.8		—		—		181.8		181.8		—		—
Asset Retirement Obligations	Asset Retirement Obligations	121.0		34.7		64.1		4.2		115.0		33.6		59.8		4.1		Asset Retirement Obligations	129.2		36.5		68.0		4.5		127.9		35.9		68.2		4.4
Other Regulatory Assets	Other Regulatory Assets	189.5		28.1		33.5		15.2		150.0		29.9		37.7		15.8		Other Regulatory Assets	286.5		25.3		107.9		12.5		322.5		26.2		114.0		14.4
Total Regulatory Assets	Total Regulatory Assets	5,732.6		2,060.2		1,680.5		736.9		5,715.8		2,084.8		1,579.2		786.4		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	Less: Current Portion	1,163.4		396.4		419.7		93.2		1,129.1		371.6		444.0		107.2		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	Total Long-Term Regulatory Assets	$	4,569.2	$	1,663.8	$	1,260.8	$	643.7	$	4,586.7	$	1,713.2	$	1,135.2	$	679.2	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 ~~$286.8~~$223.6 million (including ~~$123.2~~$146.5 million for CL&P, ~~$91.1~~$19.7 million for NSTAR Electric and ~~$1.3~~$1.1 million for PSNH) and ~~$252.5~~$210.8 million (including ~~$114.9~~$135.9 million for CL&P, ~~$85.0~~$19.8 million for NSTAR Electric and ~~$3.4~~$1.0 million for PSNH) of additional regulatory costs as of ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~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 ~~June 30, 2022~~both March 31, 2023 and December 31, ~~2021,~~2022, these regulatory costs included incremental COVID-19 related non-tracked uncollectible expense deferred of ~~$37.6 million and $33.0~~$29.8 million at Eversource, ~~$15.3 million and $18.0~~$11.8 million at CL&P, and ~~$4.8 million and $6.1~~$2.2 million at NSTAR ~~Electric, respectively.~~Electric.

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


		As of June 30, 2022								As of December 31, 2021									As of March 31, 2023								As of December 31, 2022
(Millions of Dollars)	(Millions of Dollars)	Eversource		CL&P		NSTAR Electric		PSNH		Eversource		CL&P		NSTAR Electric		PSNH		(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	EDIT due to Tax Cuts and Jobs Act of 2017	$	2,646.1	$	989.4	$	962.1	$	353.0	$	2,685.2	$	996.1	$	984.5	$	359.2	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	Cost of Removal	653.9		113.6		395.0		19.0		649.6		100.1		381.0		17.2		Cost of Removal	705.4		144.2		412.9		20.2		670.6		130.8		405.3		14.7
Regulatory Tracking Mechanisms	Regulatory Tracking Mechanisms	701.9		319.4		232.7		99.8		448.4		182.0		185.1		107.0		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	Deferred Portion of Non-Service Income Components of Pension, SERP and PBOP	209.7		23.3		115.2		21.8		148.3		12.0		90.7		14.9		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																		AFUDC - Transmission	103.8		49.8		54.0		—		98.2		48.2		50.0		—
Benefit Costs	Benefit Costs	116.0		—		92.4		—		133.5		—		107.4		—		Benefit Costs	49.2		0.6		27.1		—		55.4		0.7		31.4		—
AFUDC - Transmission		88.9		44.9		44.0		—		81.0		43.2		37.8		—
CL&P Settlement Agreement and Storm Performance Penalty		6.4		6.4		—		—		81.3		81.3		—		—
Other Regulatory Liabilities	Other Regulatory Liabilities	223.7		57.9		4.4		6.7		241.4		45.1		0.8		3.3		Other Regulatory Liabilities	219.7		44.0		14.6		6.6		215.9		40.6		14.5		6.5
Total Regulatory Liabilities	Total Regulatory Liabilities	4,646.6		1,554.9		1,845.8		500.3		4,468.7		1,459.8		1,787.3		501.6		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	Less: Current Portion	759.7		337.2		274.1		106.6		602.4		266.5		228.2		120.2		Less: Current Portion	650.5		124.6		375.0		86.6		890.8		336.0		373.2		162.0
Total Long-Term Regulatory Liabilities	Total Long-Term Regulatory Liabilities	$	3,886.9	$	1,217.7	$	1,571.7	$	393.7	$	3,866.3	$	1,193.3	$	1,559.1	$	381.4	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	Eversource	As of June 30, 2022		As of December 31, 2021		Eversource	As of March 31, 2023		As of December 31, 2022
(Millions of Dollars)	(Millions of Dollars)					(Millions of Dollars)
Distribution - Electric	Distribution - Electric	$	18,001.8	$	17,679.1	Distribution - Electric	$	18,618.6	$	18,326.2
Distribution - Natural Gas	Distribution - Natural Gas	6,819.5		6,694.8		Distribution - Natural Gas	7,562.8		7,443.8
Transmission - Electric	Transmission - Electric	13,229.5		12,882.4		Transmission - Electric	13,884.0		13,709.3
Distribution - Water	Distribution - Water	1,940.2		1,900.9		Distribution - Water	2,122.5		2,112.6
Solar	Solar	200.9		200.9		Solar	200.8		200.8
Utility	Utility	40,191.9		39,358.1		Utility	42,388.7		41,792.7
Other (1)	Other (1)	1,630.1		1,469.5		Other (1)	1,791.7		1,738.1
Property, Plant and Equipment, Gross	Property, Plant and Equipment, Gross	41,822.0		40,827.6		Property, Plant and Equipment, Gross	44,180.4		43,530.8
Less: Accumulated Depreciation	Less: Accumulated Depreciation					Less: Accumulated Depreciation
Utility	Utility	(9,046.9)		(8,885.2)		Utility	(9,317.7)		(9,167.4)
Other	Other	(640.1)		(580.1)		Other	(744.7)		(706.1)
Total Accumulated Depreciation	Total Accumulated Depreciation	(9,687.0)		(9,465.3)		Total Accumulated Depreciation	(10,062.4)		(9,873.5)
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net	32,135.0		31,362.3		Property, Plant and Equipment, Net	34,118.0		33,657.3
Construction Work in Progress	Construction Work in Progress	2,272.2		2,015.4		Construction Work in Progress	2,626.9		2,455.5
Total Property, Plant and Equipment, Net	Total Property, Plant and Equipment, Net	$	34,407.2	$	33,377.7	Total Property, Plant and Equipment, Net	$	36,744.9	$	36,112.8


		As of June 30, 2022						As of December 31, 2021							As of March 31, 2023						As of December 31, 2022
(Millions of Dollars)	(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Distribution - Electric	Distribution - Electric	$	7,252.7	$	8,265.0	$	2,524.4	$	7,117.6	$	8,105.5	$	2,496.2	Distribution - Electric	$	7,510.8	$	8,516.7	$	2,631.4	$	7,370.1	$	8,410.0	$	2,586.4
Transmission - Electric	Transmission - Electric	5,986.3		5,207.0		2,037.9		5,859.0		5,090.5		1,934.6		Transmission - Electric	6,235.2		5,382.8		2,267.6		6,165.1		5,333.8		2,212.0
Solar	Solar	—		200.9		—		—		200.9		—		Solar	—		200.8		—		—		200.8		—
Property, Plant and Equipment, Gross	Property, Plant and Equipment, Gross	13,239.0		13,672.9		4,562.3		12,976.6		13,396.9		4,430.8		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	Less: Accumulated Depreciation	(2,589.2)		(3,311.0)		(911.9)		(2,572.1)		(3,227.3)		(908.4)		Less: Accumulated Depreciation	(2,610.4)		(3,429.3)		(940.0)		(2,567.1)		(3,381.2)		(912.3)
Property, Plant and Equipment, Net	Property, Plant and Equipment, Net	10,649.8		10,361.9		3,650.4		10,404.5		10,169.6		3,522.4		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	Construction Work in Progress	441.2		787.5		169.8		399.0		707.0		134.1		Construction Work in Progress	494.7		1,148.0		189.0		498.9		1,063.6		174.1
Total Property, Plant and Equipment, Net	Total Property, Plant and Equipment, Net	$	11,091.0	$	11,149.4	$	3,820.2	$	10,803.5	$	10,876.6	$	3,656.5	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.

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 June 30, 2022						As of December 31, 2021								As of March 31, 2023						As of December 31, 2022
CL&P (Millions of Dollars)	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		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	Current Derivative Assets	Level 3	$	15.2	$	(0.5)	$	14.7	$	14.7	$	(1.0)	$	13.7	Current Derivative Assets	Level 3	$	17.0	$	(0.5)	$	16.5	$	16.3	$	(0.5)	$	15.8
Long-Term Derivative Assets	Long-Term Derivative Assets	Level 3	37.7		(1.1)		36.6		46.9		(0.9)		46.0		Long-Term Derivative Assets	Level 3	24.9		(0.8)		24.1		28.8		(0.9)		27.9
Current Derivative Liabilities	Current Derivative Liabilities	Level 3	(75.9)		—		(75.9)		(73.5)		—		(73.5)		Current Derivative Liabilities	Level 3	(85.1)		—		(85.1)		(81.6)		—		(81.6)
Long-Term Derivative Liabilities	Long-Term Derivative Liabilities	Level 3	(188.7)		—		(188.7)		(235.4)		—		(235.4)		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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021~~2022 were ~~675~~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.

For the three months ended June 30, 2022 and 2021, there were gains of $2.6 million and $0.9 million, respectively, deferred as regulatory costs, which reflect the change in fair value associated with Eversource's derivative contracts. For the six months ended June 30, 2022 and 2021, there were gains of $8.8 million and losses of $10.2 million, respectively.

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 June 30, 2022								As of December 31, 2021									As of March 31, 2023								As of December 31, 2022
CL&P	CL&P	Range				Average			Period Covered	Range				Average			Period Covered	CL&P	Range				Average			Period Covered	Range				Average			Period Covered
Forward Reserve Prices	Forward Reserve Prices	$	0.50	—	$0.50	$	0.50	per kW-Month	2022 - 2024	$	0.50	—	$1.15	$	0.82	per kW-Month	2022 - 2024	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 ~~3.9~~2.3 percent through ~~8.2~~6.6 percent, or a weighted average of ~~7.1~~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.

As of December 31, 2021, Level 3 unobservable inputs also utilized in the valuation of CL&P’s capacity-related contracts included capacity prices of $2.61 per kW-Month over the period 2025 through 2026. Beginning in the first quarter of 2022, these capacity price inputs are now observable.

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	CL&P	For the Three Months Ended June 30,				For the Six Months Ended June 30,				CL&P	For the Three Months Ended March 31,
(Millions of Dollars)	(Millions of Dollars)	2022		2021		2022		2021		(Millions of Dollars)		2023		2022
Derivatives, Net:	Derivatives, Net:									Derivatives, Net:
Fair Value as of Beginning of Period	Fair Value as of Beginning of Period	$	(229.4)	$	(293.1)	$	(249.2)	$	(293.1)	Fair Value as of Beginning of Period		$	(181.8)	$	(249.2)
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets		2.6		0.9		8.8		(11.5)
Net Realized/Unrealized (Losses)/Gains Included in Regulatory Assets										Net Realized/Unrealized (Losses)/Gains Included in Regulatory Assets		(1.9)		6.2
Settlements	Settlements	13.5		12.5		27.1		24.9		Settlements		14.9		13.6
Fair Value as of End of Period	Fair Value as of End of Period	$	(213.3)	$	(279.7)	$	(213.3)	$	(279.7)	Fair Value as of End of Period		$	(168.8)	$	(229.4)

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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021~~2022 was ~~$26.4~~$19.6 million and ~~$40.2~~$20.0 million, respectively. For the three months ended ~~June 30,~~March 31, 2023 and 2022, ~~and 2021,~~ there were unrealized ~~losses~~gains of ~~$4.7~~$0.8 million and unrealized ~~gains~~losses of ~~$1.9~~$4.4 million, respectively, recorded in Other Income, Net related to these equity securities, respectively. For the six months ended June 30, 2022 and 2021, there were unrealized losses of $9.1 million and unrealized gains of $3.0 million recorded in Other Income, Net related to these equity securities, respectively.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 ~~$182.4~~$170.9 million and ~~$214.0~~$170.1 million as of ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~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 June 30, 2022 As of December 31, 2021
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 $ 207.9 $ 0.5 $ (12.3) $ 196.1 $ 214.5 $ 5.1 $ (0.2) $ 219.4

Eversource's debt securities include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts in the amounts of $174.4 million and $189.9 million as of June 30, 2022 and December 31, 2021, respectively.


	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 ~~have been no significant~~were $1.2 million of unrealized losses ~~and~~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 ~~and six~~ months ended ~~June 30,~~March 31, 2023 and 2022, ~~and 2021,~~ and no allowance for credit losses as of ~~June 30, 2022.~~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 ~~June 30, 2022,~~March 31, 2023, the contractual maturities of available-for-sale debt securities were as follows:


Eversource (Millions of Dollars)	Eversource (Millions of Dollars)	Amortized Cost		Fair Value		Eversource (Millions of Dollars)	Amortized Cost		Fair Value
Less than one year (1)	Less than one year (1)	$	18.5	$	18.4	Less than one year (1)	$	39.8	$	38.9
One to five years	One to five years	57.6		56.7		One to five years	42.5		41.1
Six to ten years	Six to ten years	41.2		38.0		Six to ten years	35.6		32.8
Greater than ten years	Greater than ten years	90.6		83.0		Greater than ten years	78.6		69.1
Total Debt Securities	Total Debt Securities	$	207.9	$	196.1	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 June 30, 2022 As of December 31, 2021
Level 1:
Mutual Funds and Equities $ 208.8 $ 254.2
Money Market Funds 17.2 31.3
Total Level 1 $ 226.0 $ 285.5
Level 2:
U.S. Government Issued Debt Securities (Agency and Treasury) $ 84.2 $ 81.3
Corporate Debt Securities 54.9 65.3
Asset-Backed Debt Securities 9.6 12.6
Municipal Bonds 13.8 12.3
Other Fixed Income Securities 16.4 16.6
Total Level 2 $ 178.9 $ 188.1
Total Marketable Securities $ 404.9 $ 473.6


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, ~~2026.~~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, ~~2026. This revolving credit facility~~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							Borrowings Outstanding as of								Available Borrowing Capacity as of								Weighted-Average Interest Rate as of
		June 30, 2022		December 31, 2021			June 30, 2022	December 31, 2021			June 30, 2022				December 31, 2021			March 31, 2023				December 31, 2022				March 31, 2023				December 31, 2022				March 31, 2023				December 31, 2022
(Millions of Dollars)	(Millions of Dollars)									(Millions of Dollars)
Eversource Parent Commercial Paper Program	Eversource Parent Commercial Paper Program	$	124.5		$	1,343.0		$	1,875.5				$	657.0						1.81	%			0.31	%	Eversource Parent Commercial Paper Program		$	1,048.0			$	1,442.2			$	952.0			$	557.8	5.22	%	4.63	%
NSTAR Electric Commercial Paper Program	NSTAR Electric Commercial Paper Program	63.0		162.5			587.0	487.5			1.63	%			0.14	%	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 ~~June 30, 2022~~March 31, 2023 or December 31, ~~2021.~~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 ~~June 30, 2022.~~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. As a result of the NSTAR Gas long-term debt issuance in July 2022, $88.7 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified as Long-Term Debt as of June 30, 2022.

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 ~~June 30, 2022,~~March 31, 2023, there were intercompany loans from Eversource parent to CL&P of ~~$67.5~~$318.0 million and to PSNH of ~~$89.3 million, and to a subsidiary of NSTAR Electric of $3.2~~$121.1 million. As of December 31, ~~2021,~~2022, there were intercompany loans from Eversource parent to PSNH of ~~$110.6~~$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.~~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.

~~Availability under Long-Term Debt Issuance Authorizations:~~ ~~On June 14, 2022, the DPU approved NSTAR Gas’ request for authorization to issue up to $325 million in long-term debt through December 31, 2024.~~

2625

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

~~(Millions of Dollars)~~

~~Issuance/(Repayment)~~

~~Issue Date or Repayment Date~~

~~Maturity Date~~

Use of Proceeds for Issuance/
Repayment Information

~~NSTAR Electric:~~

~~4.55% 2022 Debentures~~

~~450.0~~

~~May 2022~~

~~June 2052~~

~~Repaid short-term debt, paid capital expenditures and working capital~~

~~Other:~~

~~Eversource Parent 2.90% Series V Senior Notes~~

~~650.0~~

~~February 2022~~

~~March 2027~~

~~Repaid Series K Senior Notes at maturity and short-term debt~~

~~Eversource Parent 3.38% Series W Senior Notes~~

~~650.0~~

~~February 2022~~

~~March 2032~~

~~Repaid Series K Senior Notes at maturity and short-term debt~~

~~Eversource Parent 4.20% Series X Senior Notes~~

~~900.0~~

~~June 2022~~

~~June 2024~~

~~Repaid short-term debt and paid working capital~~

~~Eversource Parent 4.60% Series Y Senior Notes~~

~~600.0~~

~~June 2022~~

~~July 2027~~

~~Repaid short-term debt and paid working capital~~

~~Eversource Parent 2.75% Series K Senior Notes~~

~~(750.0)~~

~~March 2022~~

~~Paid at maturity~~

~~Yankee Gas 8.48% Series B First Mortgage Bonds~~

~~(20.0)~~

~~March 2022~~

~~Paid at maturity~~

~~EGMA 4.70% Series C First Mortgage Bonds~~

~~100.0~~

~~June 2022~~

~~June 2052~~

~~Repaid short-term debt, paid capital expenditures and for general corporate purposes~~

~~NSTAR Gas 4.40% Series V First Mortgage Bonds~~

~~125.0~~

~~July 2022~~

~~August 2032~~

~~Repaid short-term debt, paid capital expenditures and for general corporate purposes~~

(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

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

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)	(Millions of Dollars)					(Millions of Dollars)
PSNH Balance Sheets:	PSNH Balance Sheets:	As of June 30, 2022		As of December 31, 2021		PSNH Balance Sheets:	As of March 31, 2023		As of December 31, 2022
Restricted Cash - Current Portion (included in Current Assets)	Restricted Cash - Current Portion (included in Current Assets)	$	30.7	$	31.1	Restricted Cash - Current Portion (included in Current Assets)	$	18.7	$	32.4
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2		Restricted Cash - Long-Term Portion (included in Other Long-Term Assets)	3.2		3.2
Securitized Stranded Cost (included in Regulatory Assets)	Securitized Stranded Cost (included in Regulatory Assets)	457.3		478.9		Securitized Stranded Cost (included in Regulatory Assets)	424.9		435.7
Other Regulatory Liabilities (included in Regulatory Liabilities)	Other Regulatory Liabilities (included in Regulatory Liabilities)	5.2		5.4		Other Regulatory Liabilities (included in Regulatory Liabilities)	8.8		6.0
Accrued Interest (included in Other Current Liabilities)	Accrued Interest (included in Other Current Liabilities)	7.2		7.5		Accrued Interest (included in Other Current Liabilities)	2.7		6.9
Rate Reduction Bonds - Current Portion	Rate Reduction Bonds - Current Portion	43.2		43.2		Rate Reduction Bonds - Current Portion	43.2		43.2
Rate Reduction Bonds - Long-Term Portion	Rate Reduction Bonds - Long-Term Portion	432.1		453.7		Rate Reduction Bonds - Long-Term Portion	388.9		410.5


(Millions of Dollars) PSNH Income Statements:	(Millions of Dollars) PSNH Income Statements:	For the Three Months Ended				For the Six Months Ended				(Millions of Dollars) PSNH Income Statements:	For the Three Months Ended
		June 30, 2022		June 30, 2021		June 30, 2022		June 30, 2021				March 31, 2023		March 31, 2022
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)	$	10.8	$	10.8	$	21.6	$	21.6	Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net)		$	10.8	$	10.8
Interest Expense on RRB Principal (included in Interest Expense)	Interest Expense on RRB Principal (included in Interest Expense)	4.3		4.6		8.7		9.3		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/(income)~~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 June 30, 2022 For the Three Months Ended June 30, 2022
(Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH
Service Cost $ 17.5 $ 4.7 $ 3.4 $ 1.7 $ 3.0 $ 0.5 $ 0.5 $ 0.3
Interest Cost 38.6 7.8 8.2 4.2 5.1 0.9 1.3 0.6
Expected Return on Plan Assets (130.7) (26.5) (32.1) (14.0) (22.6) (2.8) (10.6) (1.7)
Actuarial Losses, net 28.4 4.0 8.1 1.9 — — — —
Prior Service Cost/(Credit) 0.3 — 0.1 — (5.4) 0.3 (4.2) 0.1
Total Net Periodic Benefit Plan Income $ (45.9) $ (10.0) $ (12.3) $ (6.2) $ (19.9) $ (1.1) $ (13.0) $ (0.7)
Intercompany Income Allocations N/A $ (4.1) $ (3.2) $ (0.9) N/A $ (0.9) $ (0.9) $ (0.3)
Pension and SERP PBOP
For the Six Months Ended June 30, 2022 For the Six Months Ended June 30, 2022
(Millions of Dollars) Eversource CL&P NSTAR
Electric PSNH Eversource CL&P NSTAR
Electric PSNH
Service Cost $ 35.2 $ 9.2 $ 7.0 $ 3.5 $ 5.8 $ 1.0 $ 1.0 $ 0.5
Interest Cost 77.2 15.6 16.3 8.4 10.1 1.8 2.6 1.1
Expected Return on Plan Assets (262.4) (53.1) (64.1) (28.1) (45.0) (5.6) (21.2) (3.3)
Actuarial Losses, net 59.1 8.2 16.6 4.1 — — — —
Prior Service Cost/(Credit) 0.7 — 0.2 — (10.8) 0.5 (8.5) 0.2
Total Net Periodic Benefit Plan Income $ (90.2) $ (20.1) $ (24.0) $ (12.1) $ (39.9) $ (2.3) $ (26.1) $ (1.5)
Intercompany Income Allocations N/A $ (7.9) $ (6.1) $ (1.7) N/A $ (1.8) $ (1.8) $ (0.6)
Pension and SERP PBOP
For the Three Months Ended June 30, 2021 For the Three Months Ended June 30, 2021
(Millions of Dollars) Eversource CL&P NSTAR
Electric PSNH Eversource CL&P NSTAR
Electric PSNH
Service Cost $ 18.4 $ 5.5 $ 3.9 $ 2.2 $ 3.3 $ 0.6 $ 0.6 $ 0.3
Interest Cost 27.1 6.7 6.7 3.6 4.2 0.8 1.1 0.4
Expected Return on Plan Assets (87.4) (21.7) (27.1) (11.8) (19.8) (2.6) (9.2) (1.5)
Actuarial Loss 47.8 10.8 15.3 5.2 1.3 0.4 0.5 0.1
Prior Service Cost/(Credit) 0.3 — 0.1 — (5.3) 0.3 (4.2) 0.1
Total Net Periodic Benefit Plan Expense/(Income) $ 6.2 $ 1.3 $ (1.1) $ (0.8) $ (16.3) $ (0.5) $ (11.2) $ (0.6)
Intercompany Expense/(Income) Allocations N/A $ 2.3 $ 2.5 $ 0.7 N/A $ (0.6) $ (0.6) $ (0.2)
Pension and SERP PBOP
For the Six Months Ended June 30, 2021 For the Six Months Ended June 30, 2021
(Millions of Dollars) Eversource CL&P NSTAR
Electric PSNH Eversource CL&P NSTAR
Electric PSNH
Service Cost $ 39.7 $ 11.8 $ 7.9 $ 4.4 $ 6.8 $ 1.2 $ 1.2 $ 0.6
Interest Cost 59.7 14.0 13.4 7.2 8.6 1.6 2.2 0.9
Expected Return on Plan Assets (196.3) (43.3) (54.0) (23.7) (39.5) (5.2) (18.5) (3.0)
Actuarial Loss 109.4 23.8 30.8 10.1 3.9 0.8 1.1 0.3
Prior Service Cost/(Credit) 0.6 — 0.2 — (10.6) 0.5 (8.4) 0.2
Total Net Periodic Benefit Plan Expense/(Income) $ 13.1 $ 6.3 $ (1.7) $ (2.0) $ (30.8) $ (1.1) $ (22.4) $ (1.0)
Intercompany Expense/(Income) Allocations N/A $ 3.6 $ 4.0 $ 1.2 N/A $ (0.9) $ (1.0) $ (0.3)














	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)

~~Eversource Contributions:~~ Based on the current status of the Pension Plans and federal pension funding requirements, there is no minimum funding requirement for our Pension Plans for 2022. Eversource currently expects to make contributions between $100 million to $175 million in 2022, most of which will be contributed by Eversource Service, however the planned contribution is discretionary and subject to change. Eversource currently estimates contributing $2.4 million to the PBOP Plans in 2022.

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 June 30, 2022			As of December 31, 2021				As of March 31, 2023			As of December 31, 2022
		Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)			Number of Sites	Reserve (in millions)		Number of Sites	Reserve (in millions)
Eversource	Eversource	62	$	121.3	61	$	115.4	Eversource	59	$	121.2	59	$	122.6
CL&P	CL&P	14	14.3		14	13.9		CL&P	13	13.6		13	13.9
NSTAR Electric	NSTAR Electric	11	3.6		11	3.3		NSTAR Electric	10	3.4		10	3.4
PSNH	PSNH	9	6.3		9	6.3		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 ~~$110.5~~$111.7 million and ~~$105.6~~$112.6 million as of ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~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. Long-Term Contractual Arrangements~~

~~The following is an update to the current status of long-term contractual arrangements set forth in Note 13B of the Eversource 2021 Form 10-K.~~

~~Renewable Energy: Renewable energy contracts include non-cancelable commitments under contracts of NSTAR Electric for the purchase of energy and RECs from renewable energy facilities.~~
NSTAR Electric
(Millions of Dollars) 2022 2023 2024 2025 2026 Thereafter Total
Renewable Energy $ 50.4 $ 78.3 $ 269.4 $ 315.8 $ 322.1 $ 5,812.2 $ 6,848.2

~~The table includes long-term commitments of NSTAR Electric~~ pertaining to the Vineyard Wind LLC contract awarded under the Massachusetts Clean Energy 83C procurement solicitation. NSTAR Electric, along with other Massachusetts distribution companies, entered into 20-year contracts to purchase electricity generated by this 800 megawatt offshore wind project. Construction on the Vineyard Wind project commenced in 2022. Estimated energy costs under this contract are expected to begin when the facilities are in service in 2024 and range between $240 million and $375 million per year und~~er NSTAR Electric’s 20-year contract, totaling approximately $6.0 billion.~~

C.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 ~~$4.7~~$5.4 million and ~~$7.3~~$4.2 million as of ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~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 June 30, 2022
As of March 31, 2023						As of March 31, 2023
Company (Obligor)	Company (Obligor)	Description	Maximum Exposure (in millions)		Expiration Dates	Company (Obligor)	Description	Maximum Exposure (in millions)		Expiration Dates
North East Offshore LLC	North East Offshore LLC	Construction-related purchase agreements with third-party contractors (1)	$	889.9	(1)	North East Offshore LLC	Construction-related purchase agreements with third-party contractors (1)	$	726.2	(1)
Sunrise Wind LLC	Sunrise Wind LLC	Construction-related purchase agreements with third-party contractors (2)	353.9		2025 - 2026	Sunrise Wind LLC	Construction-related purchase agreements with third-party contractors (2)	668.6		2025 - 2028
Revolution Wind, LLC	Revolution Wind, LLC	Construction-related purchase agreements with third-party contractors (3)	353.8		2024 - 2027	Revolution Wind, LLC	Construction-related purchase agreements with third-party contractors (3)	409.7		2024 - 2027
South Fork Wind, LLC	South Fork Wind, LLC	Construction-related purchase agreements with third-party contractors (4)	165.1		2023 - 2026	South Fork Wind, LLC	Construction-related purchase agreements with third-party contractors (4)	126.2		2023 - 2026
Eversource Investment LLC	Eversource Investment LLC	Funding and indemnification obligations of North East Offshore LLC (5)	100.9		(5)	Eversource Investment LLC	Funding and indemnification obligations of North East Offshore LLC (5)	68.9		(5)
South Fork Wind, LLC	South Fork Wind, LLC	Power Purchase Agreement Security (6)	7.1		(6)	South Fork Wind, LLC	Power Purchase Agreement Security (6)	7.1		(6)
Sunrise Wind LLC	Sunrise Wind LLC	OREC capacity production (7)	2.2		(7)	Sunrise Wind LLC	OREC capacity production (7)	11.0		(7)
Bay State Wind LLC	Bay State Wind LLC	Real estate purchase	2.5		2023	Bay State Wind LLC	Real estate purchase	2.5		2023
South Fork Wind, LLC	South Fork Wind, LLC	Transmission interconnection	1.2		—	South Fork Wind, LLC	Transmission interconnection	1.2		—
Eversource Investment LLC	Eversource Investment LLC	Letters of Credit (8)	4.3		—	Eversource Investment LLC	Letters of Credit (8)	4.3		—
Various	Various	Surety bonds (9)	35.7		2022 - 2023	Various	Surety bonds (9)	37.2		2023 - 2024
Eversource Service	Eversource Service	Lease payments for real estate	0.6		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 ~~$464.7~~$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 ~~April 2026~~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 ~~$409.3~~$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 ~~October~~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 ~~$207.1~~$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 ~~guarantee~~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, ~~Eversource parent~~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.

D.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. The Yankee Companies filed claims seeking monetary damages totaling $120.4 million for CYAPC, YAEC and MYAPC,~~Claims resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2017 to ~~2020 (DOE~~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).~~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 ~~third~~fourth quarter of 2023.

E.D. FERC ROE Complaints

~~NaN~~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 3three 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, ~~the~~ 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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021.~~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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021.~~2022.

On October 16, 2018, FERC issued an order on all 4four 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 ~~are currently under appeal with~~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'~~owners’ two complaint cases to the ~~NETOs'~~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.

~~F. Eversource and NSTAR Electric Boston Harbor Civil Action~~

In 2016, the United States Attorney on behalf of the United States Army Corps of Engineers filed a civil action in the United States District Court for the District of Massachusetts against NSTAR Electric, HEEC, and the Massachusetts Water Resources Authority (together with NSTAR Electric and HEEC, the "Defendants"). The action alleged that the Defendants failed to comply with certain permitting requirements related to the placement of the HEEC-owned electric distribution cable beneath Boston Harbor. The parties reached a settlement pursuant to which HEEC agreed to install a new 115kV distribution cable across Boston Harbor to Deer Island, utilizing a different route, and remove portions of the existing cable. Construction of the new distribution cable was completed in August 2019, and removal of the portions of the existing cable was completed in January 2020.

NSTAR Electric and HEEC continue to finalize the resolution of certain long-term environmental restoration efforts, as required under the current permit. Upon completion of these restoration efforts and subsequent resolution with the United States Army Corps of Engineers, such litigation is expected to be dismissed with prejudice.

~~G. CL&P Regulatory Matters~~

~~CL&P Tropical Storm Isaias Response Investigation:~~ In August 2020, PURA opened a docket to investigate the preparation for and response to Tropical Storm Isaias by Connecticut utilities, including CL&P. On April 28, 2021, PURA issued a final decision on CL&P’s compliance with its emergency response plan that concluded CL&P failed to comply with certain storm performance standards and was imprudent in certain instances. Specifically, PURA concluded that CL&P did not satisfy the performance standards for managing its municipal liaison program, timely removing electrical hazards from blocked roads, communicating critical information to its customers, or meeting its obligation to secure adequate external contractor and mutual aid resources in a timely manner. Based on its findings, PURA ordered CL&P to adjust its future rates in a pending or future rate proceeding to reflect a monetary penalty in the form of a downward adjustment of 90 basis points in its allowed rate of return on equity (ROE), which is currently 9.25 percent. In its decision, PURA explained that additional monetary penalties and further enforcement orders pursuant to Connecticut statute would be considered in a separate proceeding that was initiated on May 6, 2021.

On May 6, 2021, as part of the penalty proceeding, PURA issued a notice of violation that included an assessment of $30 million, consisting of a $28.4 million civil penalty for non-compliance with storm performance standards to be provided as credits on customer bills and a $1.6 million fine for violations of accident reporting requirements to be paid to the State of Connecticut’s general fund. On July 14, 2021, PURA issued a final decision in this penalty proceeding that included an assessment of $28.6 million, maintaining the $28.4 million performance penalty and reducing the $1.6 million fine for accident reporting to $0.2 million. The $28.4 million performance penalty is currently being credited to customers on electric bills beginning on September 1, 2021 over a one-year period. The $28.4 million is the maximum statutory penalty amount under applicable Connecticut law in effect at the time of Tropical Storm Isaias, which is 2.5 percent of CL&P’s annual distribution revenues. In the first half of 2021, the liability for the performance penalty was recorded as a current regulatory liability on CL&P’s balance sheet and as a charge to Operations and Maintenance expense on the income statement. The after-tax earnings impact of this charge was $0.07 per share. The penalty was subsequently reclassified from Operations and Maintenance expense to a reduction of Operating Revenues in the third quarter of 2021 in connection with the finalization of an October 1, 2021 settlement agreement that was approved by PURA on October 27, 2021.

3230

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					Eversource				CL&P				NSTAR Electric				PSNH
(Millions of Dollars)	(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		(Millions of Dollars)	Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value		Carrying Amount		Fair Value
As of June 30, 2022:
As of March 31, 2023:																		As of March 31, 2023:
Preferred Stock Not Subject to Mandatory Redemption	Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	146.9	$	116.2	$	107.2	$	43.0	$	39.7	$	—	$	—	Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	137.1	$	116.2	$	100.8	$	43.0	$	36.3	$	—	$	—
Long-Term Debt	Long-Term Debt	20,849.2		19,531.4		4,215.9		4,053.3		4,429.7		4,295.6		1,164.2		1,027.2		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	Rate Reduction Bonds	475.3		465.0		—		—		—		—		475.3		465.0		Rate Reduction Bonds	432.1		417.3		—		—		—		—		432.1		417.3

As of December 31, 2021:
As of December 31, 2022:																		As of December 31, 2022:
Preferred Stock Not Subject to Mandatory Redemption	Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	166.3	$	116.2	$	122.3	$	43.0	$	44.0	$	—	$	—	Preferred Stock Not Subject to Mandatory Redemption	$	155.6	$	136.7	$	116.2	$	99.2	$	43.0	$	37.5	$	—	$	—
Long-Term Debt	Long-Term Debt	18,216.7		19,636.3		4,215.4		4,848.9		3,985.4		4,453.5		1,163.8		1,220.6		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	Rate Reduction Bonds	496.9		543.3		—		—		—		—		496.9		543.3		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 Six Months Ended June 30, 2022								For the Six Months Ended June 30, 2021									For the Three Months Ended March 31, 2023								For the Three Months Ended March 31, 2022
Eversource (Millions of Dollars)	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		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	Balance as of Beginning of Period	$	(0.4)	$	0.4	$	(42.3)	$	(42.3)	$	(1.4)	$	1.1	$	(76.1)	$	(76.4)	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	OCI Before Reclassifications	—		(1.3)		(2.5)		(3.8)		—		(0.5)		(2.4)		(2.9)		OCI Before Reclassifications	—		—		—		—		—		(0.8)		—		(0.8)
Amounts Reclassified from AOCI	Amounts Reclassified from AOCI	—		—		3.2		3.2		0.9		—		4.1		5.0		Amounts Reclassified from AOCI	—		1.2		2.0		3.2		—		—		1.5		1.5
Net OCI	Net OCI	—		(1.3)		0.7		(0.6)		0.9		(0.5)		1.7		2.1		Net OCI	—		1.2		2.0		3.2		—		(0.8)		1.5		0.7
Balance as of End of Period	Balance as of End of Period	$	(0.4)	$	(0.9)	$	(41.6)	$	(42.9)	$	(0.5)	$	0.6	$	(74.4)	$	(74.3)	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 ~~before reclassifications~~reclassified from AOCI relate to ~~actuarial gains and losses that arose during~~ the ~~year and were recognized in AOCI. The~~ unamortized actuarial gains and losses and prior service costs on the defined benefit plans that are amortized from AOCI into Other Income, Net over the average future employee service ~~period, and are reflected in amounts reclassified from AOCI.~~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 June 30, 2022 and December 31, 2021 Issued as of
Par Value June 30, 2022 December 31, 2021
Eversource $ 5 380,000,000 359,211,206 357,818,402
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

~~Common Share Issuances and 2022 Equity Distribution Agreement:~~ On May 11, 2022, Eversource entered into an equity distribution agreement pursuant to which it may offer and sell up to $1.2 billion of its common shares from time to time through an “at-the-market” (ATM) equity offering program. Eversource may issue and sell its common shares through its sales agents during the term of this agreement. Shares may be offered in transactions on the New York Stock Exchange, in the over-the-counter market, through negotiated transactions or otherwise. Sales may be made at either market prices prevailing at the time of sale, at prices related to such prevailing market prices or at negotiated prices. During the second quarter of 2022, Eversource issued 1,392,804 common shares, which resulted in proceeds of $126.3 million, net of issuance costs.~~Eversource used the net proceeds received for general corporate purposes.~~


	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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~2022, there were ~~12,800,177~~11,175,991 and ~~13,415,206~~11,540,218 Eversource common shares held as treasury shares, respectively. As of ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~2022, there were ~~346,411,029~~348,808,082 and ~~344,403,196~~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 ~~2021~~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 ~~June 30, 2022~~March 31, 2023 and ~~2021 and $3.8 million for each of the six months ended June 30, 2022 and 2021.~~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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021.~~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 ~~and six~~ months ended ~~June 30,~~March 31, 2023 and 2022, ~~and 2021,~~ 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)	Eversource (Millions of Dollars, except share information)	For the Three Months Ended				For the Six Months Ended				Eversource (Millions of Dollars, except share information)	For the Three Months Ended
		June 30, 2022		June 30, 2021		June 30, 2022		June 30, 2021				March 31, 2023		March 31, 2022
Net Income Attributable to Common Shareholders	Net Income Attributable to Common Shareholders	$	291.9	$	264.5	$	735.3	$	630.7	Net Income Attributable to Common Shareholders		$	491.2	$	443.4
Weighted Average Common Shares Outstanding:	Weighted Average Common Shares Outstanding:									Weighted Average Common Shares Outstanding:
Basic	Basic	345,893,714		343,844,626		345,525,030		343,761,435		Basic		349,217,147		345,156,346
Dilutive Effect	Dilutive Effect	401,764		591,070		453,276		623,758		Dilutive Effect		394,866		504,787
Diluted	Diluted	346,295,478		344,435,696		345,978,306		344,385,193		Diluted		349,612,013		345,661,133

Basic and Diluted EPS	Basic and Diluted EPS	$	0.84	$	0.77	$	2.13	$	1.83	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 June 30, 2022															For the Three Months Ended March 31, 2023
Eversource (Millions of Dollars)	Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total		Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Revenues from Contracts with Customers	Revenues from Contracts with Customers															Revenues from Contracts with Customers
Retail Tariff Sales	Retail Tariff Sales															Retail Tariff Sales
Residential	Residential	$	1,004.8	$	218.5	$	—	$	35.3	$	—	$	—	$	1,258.6	Residential	$	1,464.0	$	576.6	$	—	$	28.9	$	—	$	—	$	2,069.5
Commercial	Commercial	664.1		122.6		—		16.7		—		(1.4)		802.0		Commercial	788.4		320.0		—		15.5		—		(1.0)		1,122.9
Industrial	Industrial	88.9		43.5		—		1.1		—		(5.1)		128.4		Industrial	89.1		69.6		—		1.1		—		(5.1)		154.7
Total Retail Tariff Sales Revenues	Total Retail Tariff Sales Revenues	1,757.8		384.6		—		53.1		—		(6.5)		2,189.0		Total Retail Tariff Sales Revenues	2,341.5		966.2		—		45.5		—		(6.1)		3,347.1
Wholesale Transmission Revenues	Wholesale Transmission Revenues	—		—		334.5		—		25.1		(266.4)		93.2		Wholesale Transmission Revenues	—		—		435.0		—		—		(325.3)		109.7
Wholesale Market Sales Revenues	Wholesale Market Sales Revenues	212.6		33.2		—		0.9		—		—		246.7		Wholesale Market Sales Revenues	217.3		49.1		—		0.8		—		—		267.2
Other Revenues from Contracts with Customers	Other Revenues from Contracts with Customers	18.4		1.2		3.2		2.3		310.6		(309.8)		25.9		Other Revenues from Contracts with Customers	18.3		1.5		4.7		2.1		413.8		(412.6)		27.8
Amortization of/(Reserve for) Revenues Subject to Refund (1)		6.5		—		0.7		(0.4)		—		—		6.8

Total Revenues from Contracts with Customers	Total Revenues from Contracts with Customers	1,995.3		419.0		338.4		55.9		335.7		(582.7)		2,561.6		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	Alternative Revenue Programs	6.8		(3.0)		119.0		(1.4)		—		(113.2)		8.2		Alternative Revenue Programs	6.0		27.4		18.7		1.7		—		(16.9)		36.9
Other Revenues (2)	Other Revenues (2)	2.3		0.2		0.2		0.1		—		—		2.8		Other Revenues ~~(2)~~	5.5		1.0		0.2		0.2		—		—		6.9
Total Operating Revenues	Total Operating Revenues	$	2,004.4	$	416.2	$	457.6	$	54.6	$	335.7	$	(695.9)	$	2,572.6	Total Operating Revenues	$	2,588.6	$	1,045.2	$	458.6	$	50.3	$	413.8	$	(760.9)	$	3,795.6

		For the Six Months Ended June 30, 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		$	2,191.0	$	775.3	$	—	$	63.4	$	—	$	—	$	3,029.7
Commercial		1,325.5		380.1		—		31.3		—		(2.5)		1,734.4
Industrial		178.5		111.6		—		2.2		—		(9.6)		282.7
Total Retail Tariff Sales Revenues		3,695.0		1,267.0		—		96.9		—		(12.1)		5,046.8
Wholesale Transmission Revenues		—		—		780.7		—		49.6		(631.1)		199.2
Wholesale Market Sales Revenues		578.1		66.7		—		1.7		—		—		646.5
Other Revenues from Contracts with Customers		36.1		2.2		7.0		4.2		669.7		(662.9)		56.3
Amortization of/(Reserve for) Revenues Subject to Refund (1)		64.9		—		0.7		(0.7)		—		—		64.9
Total Revenues from Contracts with Customers		4,374.1		1,335.9		788.4		102.1		719.3		(1,306.1)		6,013.7
Alternative Revenue Programs		11.5		7.2		104.0		0.8		—		(99.6)		23.9
Other Revenues ~~(2)~~		5.1		0.7		0.4		0.2		—		—		6.4
Total Operating Revenues		$	4,390.7	$	1,343.8	$	892.8	$	103.1	$	719.3	$	(1,405.7)	$	6,044.0

3532


		For the Three Months Ended June 30, 2021
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		$	882.1	$	174.2	$	—	$	36.0	$	—	$	—	$	1,092.3
Commercial		594.1		89.6		—		16.1		—		(1.3)		698.5
Industrial		82.0		34.8		—		1.1		—		(4.4)		113.5
Total Retail Tariff Sales Revenues		1,558.2		298.6		—		53.2		—		(5.7)		1,904.3
Wholesale Transmission Revenues		—		—		416.9		—		20.3		(345.9)		91.3
Wholesale Market Sales Revenues		97.2		15.7		—		1.0		—		—		113.9
Other Revenues from Contracts with Customers		25.1		1.0		3.4		1.2		309.7		(307.0)		33.4

Total Revenues from Contracts with Customers		1,680.5		315.3		420.3		55.4		330.0		(658.6)		2,142.9
Alternative Revenue Programs		(4.8)		(3.4)		(9.3)		(2.7)		—		(1.2)		(21.4)
Other Revenues (2)		0.8		(0.1)		0.2		0.1		—		—		1.0
Total Operating Revenues		$	1,676.5	$	311.8	$	411.2	$	52.8	$	330.0	$	(659.8)	$	2,122.5

		For the Six Months Ended June 30, 2021															For the Three Months Ended March 31, 2022
Eversource (Millions of Dollars)	Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total		Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Revenues from Contracts with Customers	Revenues from Contracts with Customers															Revenues from Contracts with Customers
Retail Tariff Sales	Retail Tariff Sales															Retail Tariff Sales
Residential	Residential	$	1,948.1	$	641.1	$	—	$	63.7	$	—	$	—	$	2,652.9	Residential	$	1,186.2	$	556.8	$	—	$	28.2	$	—	$	—	$	1,771.2
Commercial	Commercial	1,154.0		297.4		—		29.8		—		(2.7)		1,478.5		Commercial	661.3		257.6		—		14.6		—		(1.1)		932.4
Industrial	Industrial	165.0		90.8		—		2.2		—		(8.0)		250.0		Industrial	89.6		68.1		—		1.1		—		(4.5)		154.3
Total Retail Tariff Sales Revenues	Total Retail Tariff Sales Revenues	3,267.1		1,029.3		—		95.7		—		(10.7)		4,381.4		Total Retail Tariff Sales Revenues	1,937.1		882.5		—		43.9		—		(5.6)		2,857.9
Wholesale Transmission Revenues	Wholesale Transmission Revenues	—		—		811.2		—		39.5		(666.9)		183.8		Wholesale Transmission Revenues	—		—		446.2		—		24.4		(364.7)		105.9
Wholesale Market Sales Revenues	Wholesale Market Sales Revenues	246.3		42.0		—		1.8		—		—		290.1		Wholesale Market Sales Revenues	365.5		33.5		—		0.8		—		—		399.8
Other Revenues from Contracts with Customers	Other Revenues from Contracts with Customers	43.4		2.4		6.8		2.4		633.5		(628.3)		60.2		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)																Amortization of/(Reserve for) Revenues Subject to Refund (1)	58.4		—		—		(0.4)		—		—		58.0
Total Revenues from Contracts with Customers	Total Revenues from Contracts with Customers	3,556.8		1,073.7		818.0		99.9		673.0		(1,305.9)		4,915.5		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	Alternative Revenue Programs	18.2		18.6		(6.6)		(0.9)		—		1.0		30.3		Alternative Revenue Programs	4.8		10.2		(15.0)		2.2		—		13.6		15.8
Other Revenues ~~(2)~~	Other Revenues ~~(2)~~	1.9		—		0.5		0.2		—		—		2.6		Other Revenues ~~(2)~~	2.8		0.4		0.2		0.1		—		—		3.5
Total Operating Revenues	Total Operating Revenues	$	3,576.9	$	1,092.3	$	811.9	$	99.2	$	673.0	$	(1,304.9)	$	4,948.4	Total Operating Revenues	$	2,386.3	$	927.6	$	435.2	$	48.5	$	383.5	$	(709.8)	$	3,471.3


		For the Three Months Ended June 30, 2022						For the Three Months Ended June 30, 2021							For the Three Months Ended March 31, 2023						For the Three Months Ended March 31, 2022
(Millions of Dollars)	(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH		(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Revenues from Contracts with Customers	Revenues from Contracts with Customers													Revenues from Contracts with Customers
Retail Tariff Sales	Retail Tariff Sales													Retail Tariff Sales
Residential	Residential	$	526.1	$	326.9	$	151.8	$	440.8	$	304.7	$	136.6	Residential	$	762.2	$	467.8	$	234.0	$	599.1	$	404.6	$	182.5
Commercial	Commercial	255.3		327.8		81.7		215.7		296.1		82.8		Commercial	295.3		384.3		108.6		242.2		331.3		88.4
Industrial	Industrial	36.0		30.6		22.3		28.4		29.1		24.5		Industrial	33.9		32.6		22.6		33.5		34.1		22.0
Total Retail Tariff Sales Revenues	Total Retail Tariff Sales Revenues	817.4		685.3		255.8		684.9		629.9		243.9		Total Retail Tariff Sales Revenues	1,091.4		884.7		365.2		874.8		770.0		292.9
Wholesale Transmission Revenues	Wholesale Transmission Revenues	115.8		163.6		55.1		195.7		160.1		61.1		Wholesale Transmission Revenues	195.8		167.8		71.4		209.1		165.2		71.9
Wholesale Market Sales Revenues	Wholesale Market Sales Revenues	143.4		47.8		21.4		68.1		18.9		10.2		Wholesale Market Sales Revenues	154.6		41.1		21.6		279.9		57.9		27.7
Other Revenues from Contracts with Customers	Other Revenues from Contracts with Customers	7.5		11.8		3.0		9.5		15.3		4.4		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)	Amortization of Revenues Subject to Refund (1)	7.2		—		—		—		—		—		Amortization of Revenues Subject to Refund (1)	0.7		—		—		58.4		—		—
Total Revenues from Contracts with Customers	Total Revenues from Contracts with Customers	1,091.3		908.5		335.3		958.2		824.2		319.6		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	Alternative Revenue Programs	92.2		14.3		19.3		(1.1)		(15.3)		2.3		Alternative Revenue Programs	24.6		(9.5)		9.6		1.3		(8.2)		(3.3)
Other Revenues (2)	Other Revenues (2)	0.2		1.6		0.7		(0.2)		0.7		0.5		Other Revenues ~~(2)~~	2.2		2.5		1.0		0.1		2.0		0.9
Eliminations	Eliminations	(148.0)		(140.7)		(48.2)		(127.3)		(122.2)		(43.6)		Eliminations	(139.7)		(141.1)		(51.5)		(145.7)		(135.3)		(53.3)
Total Operating Revenues	Total Operating Revenues	$	1,035.7	$	783.7	$	307.1	$	829.6	$	687.4	$	278.8	Total Operating Revenues	$	1,338.9	$	956.3	$	420.2	$	1,285.8	$	863.2	$	339.4

		For the Six Months Ended June 30, 2022						For the Six Months Ended June 30, 2021
(Millions of Dollars)		CL&P		NSTAR Electric		PSNH		CL&P		NSTAR Electric		PSNH
Revenues from Contracts with Customers
Retail Tariff Sales
Residential		$	1,125.2	$	731.5	$	334.3	$	986.6	$	667.1	$	294.4
Commercial		497.5		659.1		170.1		429.9		564.4		160.6
Industrial		69.5		64.7		44.3		65.2		53.6		46.2
Total Retail Tariff Sales Revenues		1,692.2		1,455.3		548.7		1,481.7		1,285.1		501.2
Wholesale Transmission Revenues		325.0		328.8		126.9		384.6		307.2		119.4
Wholesale Market Sales Revenues		423.4		105.6		49.1		177.8		43.4		25.1
Other Revenues from Contracts with Customers		15.3		23.4		5.7		16.8		27.0		7.6
Amortization of Revenues Subject to Refund (1)		65.6		—		—		—		—		—
Total Revenues from Contracts with Customers		2,521.5		1,913.1		730.4		2,060.9		1,662.7		653.3
Alternative Revenue Programs		93.4		6.1		16.0		7.8		(1.5)		5.3
Other Revenues ~~(2)~~		0.3		3.6		1.6		0.1		1.8		0.5
Eliminations		(293.7)		(276.0)		(101.5)		(251.9)		(238.6)		(86.8)
Total Operating Revenues		$	2,321.5	$	1,646.8	$	646.5	$	1,816.9	$	1,424.4	$	572.3

(1) Amortization ofof/(Reserve for) Revenues Subject to Refund within the Electric Distribution segment in the ~~second~~first quarter ~~and first half~~ 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 ~~is being~~was refunded over a one year billing period, which began September 1, 2021.

~~(2)~~ ~~Other Revenues include certain fees charged to customers that are not considered revenue from contracts with customers.~~ ~~Other Revenues also include lease revenues under lessor accounting guidance~~ of $1.0 million (including $0.2 million at CL&P and $0.6 million at NSTAR Electric) and $1.0 million (including $0.2 million at CL&P and $0.7 million at NSTAR Electric) for the three months ended June 30, 2022 and 2021, respectively, and $2.0 million (including $0.4 million at CL&P and $1.2 million at NSTAR Electric) and $2.7 million (including $0.4 million at CL&P and $1.8 million at NSTAR Electric) for the six months ended June 30, 2022 and 2021, respectively.

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.~~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, ~~Fuel~~Purchased Natural Gas and Transmission on the Eversource statements of income.

Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has 1one 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 June 30, 2022
Eversource (Millions of Dollars)		Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Operating Revenues		$	2,004.4	$	416.2	$	457.6	$	54.6	$	335.7	$	(695.9)	$	2,572.6
Depreciation and Amortization		(198.1)		(39.1)		(83.3)		(12.5)		(33.2)		1.6		(364.6)
Other Operating Expenses		(1,636.1)		(360.7)		(141.3)		(27.0)		(279.4)		692.1		(1,752.4)
Operating Income		$	170.2	$	16.4	$	233.0	$	15.1	$	23.1	$	(2.2)	$	455.6
Interest Expense		$	(60.3)	$	(16.7)	$	(37.5)	$	(8.4)	$	(53.5)	$	16.3	$	(160.1)
Other Income, Net		53.0		10.6		9.3		2.1		354.3		(335.4)		93.9
Net Income Attributable to Common Shareholders		129.0		7.7		151.5		9.0		316.0		(321.3)		291.9

		For the Six Months Ended June 30, 2022															For the Three Months Ended March 31, 2023
Eversource (Millions of Dollars)	Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total		Eversource (Millions of Dollars)	Electric Distribution		Natural Gas Distribution		Electric Transmission		Water Distribution		Other		Eliminations		Total
Operating Revenues	Operating Revenues	$	4,390.7	$	1,343.8	$	892.8	$	103.1	$	719.3	$	(1,405.7)	$	6,044.0	Operating Revenues	$	2,588.6	$	1,045.2	$	458.6	$	50.3	$	413.8	$	(760.9)	$	3,795.6
Depreciation and Amortization	Depreciation and Amortization	(549.7)		(91.1)		(165.3)		(24.8)		(63.4)		3.3		(891.0)		Depreciation and Amortization	(22.0)		(77.0)		(89.9)		(13.3)		(36.8)		2.1		(236.9)
Other Operating Expenses	Other Operating Expenses	(3,481.7)		(1,018.0)		(270.5)		(54.1)		(610.9)		1,400.8		(4,034.4)		Other Operating Expenses	(2,342.3)		(730.4)		(128.2)		(27.9)		(339.6)		759.3		(2,809.1)
Operating Income	Operating Income	$	359.3	$	234.7	$	457.0	$	24.2	$	45.0	$	(1.6)	$	1,118.6	Operating Income	$	224.3	$	237.8	$	240.5	$	9.1	$	37.4	$	0.5	$	749.6
Interest Expense	Interest Expense	$	(119.8)	$	(32.5)	$	(70.6)	$	(16.5)	$	(100.3)	$	26.4	$	(313.3)	Interest Expense	$	(69.3)	$	(21.2)	$	(41.5)	$	(9.4)	$	(85.1)	$	32.0	$	(194.5)
Other Income, Net	Other Income, Net	100.5		20.8		18.2		4.2		850.2		(828.5)		165.4		Other Income, Net	54.3		9.0		9.4		1.1		565.8		(550.6)		89.0
Net Income Attributable to Common Shareholders	Net Income Attributable to Common Shareholders	269.9		171.7		300.0		12.7		784.7		(803.7)		735.3		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	Cash Flows Used for Investments in Plant	541.8		275.4		543.6		65.6		122.7		—		1,549.1		Cash Flows Used for Investments in Plant	371.9		165.5		336.6		37.9		65.2		—		977.1

For the Three Months Ended June 30, 2021
Eversource
(Millions of Dollars)
Electric
Distribution Natural Gas
Distribution Electric
Transmission Water Distribution Other Eliminations Total
Operating Revenues $ 1,676.5 $ 311.8 $ 411.2 $ 52.8 $ 330.0 $ (659.8) $ 2,122.5
Depreciation and Amortization (132.3) (34.6) (74.5) (11.5) (28.4) 1.1 (280.2)
Other Operating Expenses (1,360.3) (257.7) (121.9) (25.4) (285.7) 660.3 (1,390.7)
Operating Income $ 183.9 $ 19.5 $ 214.8 $ 15.9 $ 15.9 $ 1.6 $ 451.6
Interest Expense $ (61.1) $ (14.6) $ (32.6) $ (8.1) $ (41.8) $ 12.8 $ (145.4)
Other Income, Net 29.9 4.6 6.8 0.9 309.2 (304.8) 46.6
Net Income Attributable to Common Shareholders 121.6 4.1 137.6 8.9 282.7 (290.4) 264.5
For the Six Months Ended June 30, 2021
Eversource
(Millions of Dollars)
Electric
Distribution Natural Gas
Distribution Electric
Transmission Water Distribution Other Eliminations Total
Operating Revenues $ 3,576.9 $ 1,092.3 $ 811.9 $ 99.2 $ 673.0 $ (1,304.9) $ 4,948.4
Depreciation and Amortization (354.3) (80.3) (148.0) (22.8) (55.7) 2.1 (659.0)
Other Operating Expenses (2,890.8) (793.6) (237.3) (50.5) (585.2) 1,305.2 (3,252.2)
Operating Income $ 331.8 $ 218.4 $ 426.6 $ 25.9 $ 32.1 $ 2.4 $ 1,037.2
Interest Expense $ (114.4) $ (28.5) $ (65.3) $ (16.0) $ (83.4) $ 24.4 $ (283.2)
Other Income, Net 50.6 8.5 12.2 1.9 733.4 (725.8) 80.8
Net Income Attributable to Common Shareholders 214.9 151.6 273.0 12.6 677.6 (699.0) 630.7
Cash Flows Used for Investments in Plant 510.4 305.9 443.2 53.8 109.9 — 1,423.2












	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 June 30, 2022 $ 26,238.1 $ 7,351.4 $ 12,938.6 $ 2,592.4 $ 23,833.9 $ (23,038.2) $ 49,916.2
As of December 31, 2021 25,411.2 7,215.9 12,377.8 2,551.1 22,674.7 (21,738.6) 48,492.1


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

3934

EVERSOURCE ENERGY AND SUBSIDIARIES

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

The following discussion and analysis should be read in conjunction with our unaudited condensed consolidated financial statements and related combined notes included in this combined Quarterly Report on Form 10-Q, ~~the combined Quarterly Report on Form 10-Q for the quarter ended March 31, 2022,~~ as well as the Eversource ~~2021~~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 ~~discussed below~~ do not represent a direct legal interest in the assets and liabilities of such business, but rather represent a direct interest in our assets and liabilities as a whole. EPS by business is a financial measure that is not recognized under GAAP (non-GAAP) ~~that~~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 ~~2022 and 2021~~ earnings and EPS excluding certain transaction and transition costs, and our 2021 earnings and EPS excluding charges at CL&P related to an October 2021 settlement agreement that included credits to customers and funding of various customer assistance initiatives and a 2021 storm performance penalty imposed on CL&P by the PURA.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 ~~2022 and 2021~~ 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 ~~the CL&P October 2021 settlement agreement, and the 2021 storm performance penalty imposed on CL&P by the PURA,~~ 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,

• ~~the negative impacts of the novel coronavirus (COVID-19) pandemic, including any new or emerging variants, on our customers, vendors, employees, regulators, and operations,~~

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

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

• acts of war or terrorism, physical attacks or grid disturbances that may damage and disrupt our electric transmission and electric,

natural gas, and water distribution systems,

• 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.

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 ~~2021~~2022 combined Annual Report on Form 10-K. This combined Quarterly Report on Form 10-Q and Eversource's ~~2021~~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 ~~Eversource Gas Company of Massachusetts (EGMA)~~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 ~~$291.9~~$491.2 million, or ~~$0.84 per share, in the second quarter of 2022, and $735.3 million, or $2.13~~$1.41 per share, in the first ~~half~~quarter of ~~2022,~~2023, compared with ~~$264.5~~$443.4 million, or ~~$0.77 per share, in the second quarter of 2021, and $630.7 million, or $1.83~~$1.28 per share, in the first ~~half~~quarter of ~~2021.~~

•2022. Our results include after-tax transaction and transition costs recorded at Eversource parent of ~~$5.5~~$0.5 million in the first quarter of 2023, compared with $5.3 million, or $0.02 per share, in the ~~second~~first quarter of 2022, and $10.8 million, or $0.03 per share, in the first half of 2022, compared with $6.8 million, or $0.02 per share, in the second quarter of 2021, and $13.0 million, or $0.04 per share, in the first half of 2021. Our first half of 2021 results also include an after-tax charge at CL&P of $22.6 million, or $0.07 per share, recorded within the electric distribution segment resulting from a PURA assessment as a result of CL&P’s preparation for and response to Tropical Storm Isaias in August 2020. Excluding transaction and transition costs, our non-GAAP earnings were $297.4 million, or $0.86 per share, in the second quarter of 2022, and $746.1 million, or $2.16 per share, in the first half of 2022, compared with $269.9 million, or $0.79 per share, in the second quarter of 2021, and $666.3 million, or $1.94 per share, in the first half of 2021.2022.

•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 ~~2026~~2027 from our regulated utility businesses in the upper half of the 5 to 7 percent range.~~We now estimate to earn within a 2022 non-GAAP earnings guidance range of between $4.04 per share and $4.14 per share, which excludes the impact of transaction and transition costs.~~

Liquidity:

•Cash flows provided by operating activities totaled ~~$841.8~~$69.2 million in the first ~~half~~quarter of ~~2022,~~2023, compared with ~~$807.4~~$371.9 million in the first ~~half~~quarter of ~~2021.~~2022. Investments in property, plant and equipment totaled ~~$1.55 billion~~$977.1 million in the first ~~half~~quarter of ~~2022,~~2023, compared with ~~$1.42 billion~~$764.6 million in the first ~~half~~quarter of ~~2021.~~2022.

•Cash and Cash Equivalents totaled ~~$29.5~~$36.0 million as of ~~June 30, 2022,~~March 31, 2023, compared with ~~$66.8~~$374.6 million as of December 31, ~~2021.~~2022. Our available borrowing capacity under our commercial paper programs totaled ~~$2.46~~$1.45 billion as of ~~June 30, 2022.~~March 31, 2023.

•In the first ~~half~~quarter of ~~2022,~~2023, we issued ~~$3.35~~$1.55 billion of new long-term debt and we repaid ~~$770~~$400 million of long-term debt.

•~~In the first half of 2022, we issued 1,392,804 common shares, which resulted in proceeds of $126.3 million, net of issuance costs.~~

•On May ~~4, 2022,~~3, 2023, our Board of Trustees approved a common share dividend payment of ~~$0.6375~~$0.675 per share, ~~paid~~payable on June 30, ~~2022~~2023 to shareholders of record as of May ~~19, 2022.~~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.

~~Strategic Items:~~

•On May 4, 2022, we announced that we have 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 have advanced our strategic review process and are working with our advisors on our outreach strategy and marketing materials, which will aid us in evaluating the alternatives available for our investment. In late July, we started

preliminary and targeted outreach to potential buyers. We expect to complete this review during 2022. 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. 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.

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 June 30,								For the Six Months Ended June 30,									For the Three Months Ended March 31,
		2022				2021				2022				2021						2023	2022
(Millions of Dollars, Except Per Share Amounts)	(Millions of Dollars, Except Per Share Amounts)	Amount		Per Share		Amount		Per Share		Amount		Per Share		Amount		Per Share		(Millions of Dollars, Except Per Share Amounts)			Amount		Per Share		Amount		Per Share
Net Income Attributable to Common Shareholders (GAAP)	Net Income Attributable to Common Shareholders (GAAP)	$	291.9	$	0.84	$	264.5	$	0.77	$	735.3	$	2.13	$	630.7	$	1.83	Net Income Attributable to Common Shareholders (GAAP)			$	491.2	$	1.41	$	443.4	$	1.28

Regulated Companies (Non-GAAP)		$	297.2	$	0.86	$	270.8	$	0.79	$	754.3	$	2.18	$	674.7	$	1.96
Regulated Companies																		Regulated Companies			$	492.4	$	1.41	$	457.1	$	1.32
Eversource Parent and Other Companies (Non-GAAP)	Eversource Parent and Other Companies (Non-GAAP)	0.2		—		(0.9)		—		(8.2)		(0.02)		(8.4)		(0.02)		Eversource Parent and Other Companies (Non-GAAP)			(0.7)		—		(8.4)		(0.02)
Non-GAAP Earnings	Non-GAAP Earnings	$	297.4	$	0.86	$	269.9	$	0.79	$	746.1	$	2.16	$	666.3	$	1.94	Non-GAAP Earnings			$	491.7	$	1.41	$	448.7	$	1.30
CL&P Storm Performance Penalty (after-tax) (1)		—		—		1.4		—		—		—		(22.6)		(0.07)
Transaction and Transition Costs (after-tax) (2)		(5.5)		(0.02)		(6.8)		(0.02)		(10.8)		(0.03)		(13.0)		(0.04)
Transaction and Transition Costs (after-tax) (1)																		Transaction and Transition Costs (after-tax) (1)			(0.5)		—		(5.3)		(0.02)
Net Income Attributable to Common Shareholders (GAAP)	Net Income Attributable to Common Shareholders (GAAP)	$	291.9	$	0.84	$	264.5	$	0.77	$	735.3	$	2.13	$	630.7	$	1.83	Net Income Attributable to Common Shareholders (GAAP)			$	491.2	$	1.41	$	443.4	$	1.28

(1) The 2021 after-tax cost relates to a charge recorded at CL&P as a result of PURA’s April 28, 2021 and July 14, 2021 decisions, which included a $28.4 million penalty for storm performance results and is currently being provided as credits to customer bills and a $1.6 million fine to the State of Connecticut’s general fund that was subsequently reduced to $0.2 million in PURA’s July 14, 2021 decision. As a result of the October 1, 2021 CL&P settlement agreement, CL&P agreed to withdraw its pending appeals related to the storm performance penalty imposed in PURA’s April 28, 2021 and July 14, 2021 decisions. Management views the CL&P storm performance penalty and the subsequent October 1, 2021 settlement agreement impacts collectively, and as not directly related to the ongoing operations of the business and therefore not an indicator of baseline operating performance. As a result, beginning in the third quarter of 2021, the storm performance penalty was presented as a non-GAAP adjustment to net income. The second quarter and first half of 2021 non-GAAP reconciliations have been recast to conform to this presentation.

~~(2)~~ ~~The~~ after-tax costs are for the ~~continuing~~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 ~~CMA~~Columbia Gas of Massachusetts (CMA) on October 9, 2020 and integrating the CMA assets onto Eversource’s systems. ~~The after-tax costs also include costs associated with our water business acquisitions and the strategic review of our offshore wind investment portfolio.~~

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 June 30, For the Six Months Ended June 30,
2022 2021 2022 2021
(Millions of Dollars, Except Per Share Amounts) Amount Per Share Amount Per Share Amount Per Share Amount Per Share
Net Income - Regulated Companies (GAAP) $ 297.2 $ 0.86 $ 272.2 $ 0.79 $ 754.3 $ 2.18 $ 652.1 $ 1.89
Electric Distribution, excluding CL&P Storm
Performance Penalty (Non-GAAP) $ 129.0 $ 0.37 $ 120.2 $ 0.35 $ 269.9 $ 0.78 $ 237.5 $ 0.69
Electric Transmission 151.5 0.44 137.6 0.40 300.0 0.87 273.0 0.79
Natural Gas Distribution 7.7 0.02 4.1 0.01 171.7 0.49 151.6 0.44
Water Distribution 9.0 0.03 8.9 0.03 12.7 0.04 12.6 0.04
Net Income - Regulated Companies (Non-GAAP) $ 297.2 $ 0.86 $ 270.8 $ 0.79 $ 754.3 $ 2.18 $ 674.7 $ 1.96
CL&P Storm Performance Penalty (after-tax) — — 1.4 — — — (22.6) (0.07)
Net Income - Regulated Companies (GAAP) $ 297.2 $ 0.86 $ 272.2 $ 0.79 $ 754.3 $ 2.18 $ 652.1 $ 1.89


	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 ~~$7.4~~$24.6 million in the ~~second~~first quarter of ~~2022,~~2023, as compared to the ~~second~~first quarter of ~~2021,~~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 ~~a base distribution rate~~and an increase ~~at NSTAR Electric effective January 1, 2022, and lower pension plan expense~~ in ~~Connecticut and New Hampshire.~~interest income primarily on regulatory deferrals. Those earnings increases were partially offset by higher operations and maintenance expense, ~~driven primarily by~~ higher ~~employee-related costs,~~interest expense, higher pension expense in Connecticut and New Hampshire, higher property and other tax expense, and higher ~~depreciation.~~

Our electric distribution segment earnings increased $55.0 million in the first half of 2022, as compared to the first half of 2021, due primarily to the absence in 2022 of the $28.6 million pre-tax charge to earnings at CL&P for a storm performance penalty imposed by PURA as a result of CL&P’s preparation for and response to Tropical Storm Isaias in August 2020 that was recorded in 2021. The after-tax impact of the CL&P storm

performance penalty was $22.6 million, or $0.07 per share. Excluding that charge, electric distribution segment earnings increased $32.4 million due primarily to higher earnings from CL&P's capital tracking mechanism due to increased electric system improvements, a base distribution rate increase at NSTAR Electric effective January 1, 2022, and lower pension plan expense in Connecticut and New Hampshire. Those earnings increases were partially offset by higher operations and maintenance expense driven primarily by higher storm costs, higher depreciation ~~higher property and other tax expense, and higher interest~~ expense.

Our electric transmission segment earnings increased ~~$13.9 million and $27.0~~$6.6 million in the ~~second~~first quarter ~~and first half~~ of ~~2022, respectively,~~2023, as compared to the ~~second~~first quarter ~~and first half~~ of ~~2021,~~2022, due primarily to a higher transmission rate base as a result of our continued investment in our transmission ~~infrastructure.~~infrastructure, partially offset by higher interest expense on short-term debt.

Our natural gas distribution segment earnings increased ~~$3.6 million and $20.1~~$6.3 million in the ~~second~~first quarter ~~and first half~~ of ~~2022, respectively,~~2023, as compared to the ~~second~~first quarter ~~and first half~~ of ~~2021,~~2022, due primarily to base distribution rate increases ~~at EGMA and NSTAR Gas~~ effective November 1, ~~2021,~~2022 at NSTAR Gas and EGMA, higher earnings from capital tracking mechanisms due to continued investments in natural gas infrastructure, and lower ~~pension plan expense at Yankee Gas.~~operations and maintenance expense. Those earnings increases were partially offset by higher ~~operations and maintenance expense, higher property tax~~depreciation expense, higher interest expense, and higher ~~depreciation~~property tax expense. Our natural gas companies' decoupled rate structure is seasonally structured and provides greater earnings in the winter heating months in correlation to higher customer usage. Therefore, the majority of the impact of the EGMA and NSTAR Gas annual base distribution rate increases were recognized by the end of the first quarter of 2022.

Our water distribution segment earnings ~~increased $0.1~~decreased $2.2 million in ~~both~~ the ~~second~~first quarter ~~and first half~~ of ~~2022,~~2023, as compared to the ~~second~~first quarter of 2022, due primarily to higher operations and ~~first half of 2021.~~maintenance expense.

Eversource Parent and Other Companies: Eversource parent and other companies’ losses decreased ~~$2.4~~$12.5 million in ~~both the second quarter and~~ the first ~~half~~quarter of ~~2022, respectively,~~2023, as compared to the ~~second~~first quarter ~~and first half~~ of ~~2021. Lower losses were~~2022, due primarily to ~~higher unrealized gains associated with our~~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 ~~return at Eversource Service as~~interest expense. Additionally, earnings benefited from a ~~result of increased investments~~decrease in ~~property, plant~~after-tax transaction and ~~equipment, and after-tax decreases of $1.3 million and $2.2 million in~~ transition costs of ~~EGMA and transaction costs~~$4.8 million in the ~~second~~first quarter ~~and first half~~ of ~~2022, respectively,~~2023, as compared to the same ~~periods~~period in ~~2021, partially offset by higher interest expense~~2022 and a ~~higher~~lower effective tax rate.

~~Pension Plan:~~ Pension plan assets and obligation are presented on a net basis and remeasured annually using a December 31st measurement date. Our future pension expense amount is dependent on plan asset returns and market performance, discount rates, and other actuarial assumptions. An underperformance of our pension plan investment returns relative to the expected returns would increase our net pension liability at December 31st, resulting in unamortized actuarial losses to be recognized in future years’ pension plan expense and a reduced expected return on assets component of pension expense. An increase in the discount rate used to determine our pension obligation would decrease our net pension liability at December 31st, resulting in unamortized actuarial gains to be recognized in future years’ pension plan expense. An increase in the discount rate at December 31st would also result in an increase in the interest cost component and a decrease in the service cost component of the subsequent year’s pension plan expense. Unamortized actuarial gains or losses arising at the December 31st measurement date are primarily from differences in actual investment performance compared to expected performance, as well as changes in the discount rate and other actuarial assumptions. These actuarial gains or losses are amortized as a component of pension plan expense over the estimated average future employee service period, which is seven years for the pension plan.

The change in total pension plan expense arising from this annual remeasurement does not fully impact earnings. Our Massachusetts utilities recover qualified pension expenses related to their distribution operations through a rate reconciling mechanism that fully tracks the change in net pension expenses each year, therefore the change in their pension expense does not impact earnings. Our electric transmission companies' rates provide for an annual true-up of estimated to actual costs, which include pension expenses, therefore the change in their pension expense does not impact earnings. Additionally, the portion of our pension expense that relates to company labor devoted to capital projects are capitalized on the balance sheet instead of being charged to expense.

~~Impact of COVID-19~~

The current and expected future financial impacts of COVID-19 as it relates to our businesses primarily relate to collectability of customer receivables and customer payment plans and the outcome of future proceedings before our state regulatory commissions to recover our incremental costs associated with COVID-19.

As of June 30, 2022, our allowance for uncollectible customer receivable balance of $457.8 million, of which $242.7 million relates to hardship accounts that are specifically recovered in rates charged to customers, adequately reflected the collection risk and net realizable value for our receivables. As of June 30, 2022 and December 31, 2021, the total amount incurred as a result of COVID-19 included in the allowance for uncollectible accounts was $63.1 million and $55.3 million at Eversource, $20.4 million and $23.9 million at CL&P, and $7.5 million and $9.0 million at NSTAR Electric, respectively. 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.

As of June 30, 2022 and December 31, 2021, a total of $37.6 million and $33.0 million, respectively, of incremental COVID-19 related non-tracked uncollectible costs were recorded on the balance sheets.

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 ~~$29.5~~$36.0 million as of ~~June 30, 2022,~~March 31, 2023, compared with ~~$66.8~~$374.6 million as of December 31, ~~2021.~~2022.

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


		Borrowings Outstanding as of					Available Borrowing Capacity as of				Weighted-Average Interest Rate as of							Borrowings Outstanding as of								Available Borrowing Capacity as of								Weighted-Average Interest Rate as of
		June 30, 2022		December 31, 2021			June 30, 2022	December 31, 2021			June 30, 2022				December 31, 2021			March 31, 2023				December 31, 2022				March 31, 2023				December 31, 2022				March 31, 2023				December 31, 2022
(Millions of Dollars)	(Millions of Dollars)									(Millions of Dollars)
Eversource Parent Commercial Paper Program	Eversource Parent Commercial Paper Program	$	124.5		$	1,343.0		$	1,875.5				$	657.0						1.81	%			0.31	%	Eversource Parent Commercial Paper Program		$	1,048.0			$	1,442.2			$	952.0			$	557.8	5.22	%	4.63	%
NSTAR Electric Commercial Paper Program	NSTAR Electric Commercial Paper Program	63.0		162.5			587.0	487.5			1.63	%			0.14	%	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 ~~June 30, 2022~~March 31, 2023 or December 31, ~~2021.~~2022.

4438

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

~~(Millions of Dollars)~~

~~Issuance/(Repayment)~~

~~Issue Date or Repayment Date~~

~~Maturity Date~~

Use of Proceeds for Issuance/
Repayment Information

~~NSTAR Electric:~~

~~4.55% 2022 Debentures~~

~~450.0~~

~~May 2022~~

~~June 2052~~

~~Repaid short-term debt, paid capital expenditures and working capital~~

~~Other:~~

~~Eversource Parent 2.90% Series V Senior Notes~~

~~650.0~~

~~February 2022~~

~~March 2027~~

~~Repaid Series K Senior Notes at maturity and short-term debt~~

~~Eversource Parent 3.38% Series W Senior Notes~~

~~650.0~~

~~February 2022~~

~~March 2032~~

~~Repaid Series K Senior Notes at maturity and short-term debt~~

~~Eversource Parent 4.20% Series X Senior Notes~~

~~900.0~~

~~June 2022~~

~~June 2024~~

~~Repaid short-term debt and paid working capital~~

~~Eversource Parent 4.60% Series Y Senior Notes~~

~~600.0~~

~~June 2022~~

~~July 2027~~

~~Repaid short-term debt and paid working capital~~

~~Eversource Parent 2.75% Series K Senior Notes~~

~~(750.0)~~

~~March 2022~~

~~Paid at maturity~~

~~Yankee Gas 8.48% Series B First Mortgage Bonds~~

~~(20.0)~~

~~March 2022~~

~~Paid at maturity~~

~~EGMA 4.70% Series C First Mortgage Bonds~~

~~100.0~~

~~June 2022~~

~~June 2052~~

~~Repaid short-term debt, paid capital expenditures and for general corporate purposes~~

~~NSTAR Gas 4.40% Series V First Mortgage Bonds~~

~~125.0~~

~~July 2022~~

~~August 2032~~

~~Repaid short-term debt, paid capital expenditures and for general corporate purposes~~

(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

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

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 ~~$9.0~~$8.3 million of interest payments in the first ~~half~~quarter of ~~2022,~~2023, and paid $21.6 million of RRB principal payments and ~~$9.6~~$9.0 million of interest payments in the first ~~half of 2021.~~

~~Common Share Issuances and 2022 Equity Distribution Agreement:~~ On May 11, 2022, Eversource entered into an equity distribution agreement pursuant to which it may offer and sell up to $1.2 billion of its common shares from time to time through an “at-the-market” (ATM) equity offering program. Eversource may issue and sell its common shares through its sales agents during the term of this agreement. Shares may be offered in transactions on the New York Stock Exchange, in the over-the-counter market, through negotiated transactions or otherwise. Sales may be made at either market prices prevailing at the time of sale, at prices related to such prevailing market prices or at negotiated prices. During the second quarter of ~~2022, Eversource issued 1,392,804 common shares, which resulted in proceeds of $126.3 million, net of issuance costs.Eversource used the net proceeds received for general corporate purposes.~~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 ~~$841.8~~$69.2 million in the first ~~half~~quarter of ~~2022,~~2023, compared with ~~$807.4~~$371.9 million in the first ~~half~~quarter of 2021. Changes in Eversource’s cash flows from operations were generally consistent with changes in its results of operations, as adjusted by changes in working capital in the normal course of business and as further discussed.2022. Operating cash flows were ~~favorably~~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,~~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 ~~income tax payments~~the first quarter of ~~$71.7 million made in 2022,~~2023, as compared to ~~2021,~~the first quarter of 2022, and is presented as a ~~$20.0 million decrease~~cash outflow in ~~pension contributions made~~Amortization on the statement of cash flows. The impact of regulatory collections are included in ~~2022, as compared to 2021.~~both Regulatory Recoveries and Amortization on the statements of cash flows. These ~~favorable~~unfavorable impacts were partially offset by ~~an increase in regulatory under-recoveries (net of regulatory amortization) driven by an increase~~a $71.2 million decrease in cash payments for storm costs, ~~and~~ the timing of cash collections ~~for regulatory tracking mechanisms,~~on our accounts receivable, the absence in 2023 of $58.4 million of customer credits ~~being~~ distributed toin 2022 at CL~~&P’s customers in the first half of 2022~~&P as a result of the October 2021 settlement agreement and the 2021 storm performance penalty for ~~its~~CL&P’s response to Tropical Storm Isaias, ~~the timing~~a decrease of ~~cash collections on our accounts receivable, a $76.1~~$25.0 million ~~payment~~ in ~~the second quarter of~~pension contributions made in 2023, as compared to 2022, ~~related to withheld property taxes at NSTAR Electric, a $74.3 million increase in cost of removal expenditures, and~~ the timing of other working capital ~~items.~~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 ~~4, 2022,~~3, 2023, our Board of Trustees approved a common share dividend payment of ~~$0.6375~~$0.675 per share, ~~paid~~payable on June 30, ~~2022~~2023 to shareholders of record as of May ~~19, 2022.~~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 ~~half~~quarter of ~~2022,~~2023, we paid cash dividends of ~~$427.9~~$229.4 million and issued non-cash dividends of ~~$11.7~~$6.0 million in the form of treasury shares, totaling dividends of ~~$439.6~~$235.4 million. In the first ~~half~~quarter of ~~2021,~~2022, we paid cash dividends of ~~$402.2~~$213.9 million and issued non-cash dividends of ~~$11.6~~$5.9 million in the form of treasury shares, totaling dividends of ~~$413.8~~$219.8 million.

In the first ~~half~~quarter of ~~2022,~~2023, CL&P, NSTAR Electric and PSNH paid ~~$146.2~~$82.6 million, ~~$143.8~~$327.4 million, and ~~$52.0~~$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 ~~half~~quarter of ~~2022,~~2023, investments for Eversource, CL&P, NSTAR Electric, and PSNH were ~~$1.55 billion, $414.4~~$977.1 million, ~~$444.0~~$255.9 million, $318.7 million, and ~~$227.0~~$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.

45Investments 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 ~~2021~~2022 Form 10-K. See Note 9B, "Commitments and Contingencies – Long-Term Contractual Arrangements," to the financial statements for discussion of material changes to our cash requirements from contractual obligations. Other than as described in the footnote, thereThere have been no material changes to our cash requirements from contractual obligations and payment schedules previously disclosed in our ~~2021~~2022 Form 10-K.

Impact of COVID-19

~~Credit Ratings:~~
~~On April 8,~~

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, ~~Fitch changed~~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’s outlook~~&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 negative to stable. On May 9, 2022, S&P revised the outlook from stable to positive for Eversource and all of its subsidiaries except for PSNH, whose outlook remains at stable. On June 15, 2022, Moody’s changed CL&P’s outlook from negative to stable.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 ~~$1.56 billion~~$789.2 million in the first ~~half~~quarter of ~~2022,~~2023, compared to ~~$1.46 billion~~$685.6 million in the first ~~half~~quarter of ~~2021.~~2022. These amounts included $~~103.8~~42.9 million and ~~$105.6~~$53.7 million in the first ~~half~~quarter of ~~2022~~2023 and ~~2021,~~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 ~~$67.9~~$16.3 million in the first ~~half~~quarter of ~~2022,~~2023, as compared to the first ~~half~~quarter of ~~2021.~~2022. A summary of electric transmission capital expenditures by company is as follows:


		For the Six Months Ended June 30,					For the Three Months Ended March 31,
(Millions of Dollars)	(Millions of Dollars)	2022		2021		(Millions of Dollars)	2023		2022
CL&P	CL&P	$	187.6	$	163.4	CL&P	$	77.4	$	93.8
NSTAR Electric	NSTAR Electric	175.0		199.8		NSTAR Electric	96.6		83.4
PSNH	PSNH	140.6		72.1		PSNH	72.8		53.3
Total Electric Transmission Segment		$	503.2	$	435.3
Total Electric Transmission						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 ~~increase access to~~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 ~~second~~fourth quarter of 2023. Construction on the last remaining upgrade, the Sudbury-Hudson Reliability Project, ~~is expected to commence~~commenced in the ~~third~~fourth quarter of 2022. We spent ~~$22.8~~$16.6 million during the first ~~half~~quarter of ~~2022~~2023 and we now expect to make additional capital expenditures of approximately ~~$160~~$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 ~~$5.8~~$7.2 million during the first ~~half~~quarter of ~~2022~~2023 and we expect to make additional capital expenditures of approximately ~~$125~~$100 million on these transmission upgrades.

On June 17, 2022, FERC approved a transmission support agreement between NSTAR Electric and Park City Wind LLC (PCW). The agreement commits NSTAR Electric to construct certain transmission facilities required to interconnect PCW’s future 800 MW offshore wind generation facility to NSTAR Electric’s transmission system. Of the total estimated $196 million project, NSTAR Electric will finance an estimated $152 million and earn a return on those specific investments over a ten-year period once the facility is in operation based on the authorized return that is in effect at the applicable time for regional transmission service under the ISO-NE Open Access Transmission Tariff. The interconnection transmission facilities are currently expected to be in-service in 2026.

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


		For the Six Months Ended June 30,															For the Three Months Ended March 31,
(Millions of Dollars)	(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		Total Electric		Natural Gas		Water		Total		(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		Total Electric		Natural Gas		Water		Total
2023																2023
Basic Business																Basic Business	$	53.1	$	62.0	$	11.7	$	126.8	$	37.1	$	3.5	$	167.4
Aging Infrastructure																Aging Infrastructure	52.1		59.4		16.5		128.0		105.5		27.7		261.2
Load Growth and Other																Load Growth and Other	25.7		31.3		3.1		60.1		10.6		0.2		70.9
Total Distribution																Total Distribution	$	130.9	$	152.7	$	31.3	$	314.9	$	153.2	$	31.4	$	499.5
2022	2022															2022
Basic Business	Basic Business	$	124.1	$	67.7	$	30.0	$	221.8	$	101.3	$	5.4	$	328.5	Basic Business	$	59.3	$	27.3	$	13.5	$	100.1	$	54.9	$	1.8	$	156.8
Aging Infrastructure	Aging Infrastructure	89.9		95.9		33.3		219.1		209.7		53.5		482.3		Aging Infrastructure	34.2		48.6		12.4		95.2		61.2		23.6		180.0
Load Growth and Other	Load Growth and Other	30.6		82.2		10.8		123.6		20.1		0.3		144.0		Load Growth and Other	14.0		36.5		5.2		55.7		8.8		0.1		64.6
Total Distribution	Total Distribution	244.6		245.8		74.1		564.5		331.1		59.2		954.8		Total Distribution	$	107.5	$	112.4	$	31.1	$	251.0	$	124.9	$	25.5	$	401.4
Solar		—		0.1		—		0.1		—		—		0.1
Total		$	244.6	$	245.9	$	74.1	$	564.6	$	331.1	$	59.2	$	954.9
2021
Basic Business		$	102.0	$	79.4	$	26.9	$	208.3	$	97.3	$	6.6	$	312.2
Aging Infrastructure		71.8		106.0		33.1		210.9		207.4		44.1		462.4
Load Growth and Other		36.0		68.2		6.6		110.8		32.4		0.3		143.5
Total Distribution		209.8		253.6		66.6		530.0		337.1		51.0		918.1
Solar		—		(1.1)		—		(1.1)		—		—		(1.1)
Total		$	209.8	$	252.5	$	66.6	$	528.9	$	337.1	$	51.0	$	917.0

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

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

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

~~Pending Acquisition of Torrington Water Company:~~ On March 7, 2022, Aquarion and The Torrington Water Company (TWC) entered into a definitive agreement pursuant to which Aquarion would acquire all outstanding shares of TWC. TWC provides regulated water service to approximately 10,100 customers in Connecticut. The acquisition has been structured as a stock-for-stock exchange and Eversource will issue between 885,000 and 925,000 common shares at closing. The application for approval of the acquisition was filed with PURA on April 1, 2022. The transaction was approved by TWC shareholders on June 16, 2022 and is expected to close in the fourth quarter of 2022.

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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021,~~2022, Eversource's total equity investment balance in its offshore wind business was ~~$1.49~~$2.16 billion and ~~$1.21~~$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 ~~have~~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 ~~have advanced our strategic review~~continue to work with interested parties through this ongoing process and are working with our advisors on our outreach strategy and marketing materials, which will aid us in evaluating the alternatives available for our investment. In late July, we started preliminary and targeted outreach to potential buyers. We expect to complete this review ~~during 2022.~~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

$98.43

Fixed price contract; no price escalation

Approved

Revolution Wind

Connecticut

304

$98.43 - $99.50

Fixed price contracts; no price escalation

Approved

South Fork Wind

New York (LIPA)

$160.33

2 percent average price escalation

Approved

South Fork Wind

New York (LIPA)

$86.25

2 percent average price escalation

Approved

Sunrise Wind

New York (NYSERDA)

924

$110.37 (1)

Fixed price contract; no price escalation

Approved

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

~~Our offshore wind~~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. ~~On April 30, 2021,~~BOEM released its Draft EIS on September 2, 2022 for the Revolution Wind ~~received BOEM’s NOI to prepare an EIS~~project and on December 16, 2022 for the ~~review~~Sunrise Wind project. The Draft EIS analyzes the potential environmental impacts of the ~~COP submitted by~~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.~~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

expected in the fourth quarter of 2023. ~~On August 31, 2021, Sunrise Wind received BOEM’s NOI to prepare an EIS for the review of the COP.~~ 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~~operate.

~~. The Sunrise Wind state siting application was deemed complete on July 1, 2021, initiating the formal review process, and~~

On September 23, 2022, Sunrise Wind filed a ~~formal notice of intent to commence settlement negotiations towards 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 ~~August 31, 2021.~~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.

~~Settlement negotiations are ongoing.~~

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:~~Process: South Fork Wind received all required approvals to start construction and the project entered the construction phase in early 2022. ~~Site preparation and onshore~~Onshore activities for the project’s underground onshore transmission line ~~and~~were completed in the first quarter of 2023. Onshore activities for the construction of the onshore interconnection facility located in East Hampton, New York ~~are underway.~~continue. Offshore ~~installation,~~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, isare expected to ~~occur in~~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 ~~$0.9~~$1.4 billion and ~~$1.0~~$1.6 billion in ~~2022~~2023 and expect to make investments for our three projects in total between ~~$3.0~~$2.1 billion and ~~$3.6~~$2.4 billion from ~~2023~~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 discussed above.~~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.

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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021.~~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 ~~June 30, 2022~~March 31, 2023 and December 31, ~~2021.~~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.

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~~Nos. 569-A and 569-B ~~are currently under appeal with~~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.

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~~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.

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 ~~half~~quarter of ~~2022,~~2023, changes made to the regulated companies’ rates did not have a material impact on their ~~earnings, financial position, or cash flows.~~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 ~~2021~~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 ~~Advanced Metering Infrastructure Filing:~~Performance Based Rate Making: On ~~July 31,~~May 26, 2021, in accordance with an October 2020 ~~CL&P submitted~~Connecticut law, PURA opened a proceeding to begin to evaluate and eventually implement performance-based regulation (PBR) for electric distribution companies. PURA ~~its proposed $512 million Advanced Metering Infrastructure investment~~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 ~~plan.~~in the second phase of the proceeding. On ~~August 17, 2021,~~April 26, 2023, PURA issued a ~~Notice~~final decision on the first phase and identified various objectives to guide PBR development and evaluate adoption of ~~Request for Amended EDC Advanced Metering Infrastructure Proposal. CL&P submitted an Amended Proposal in response to this request on November 8, 2021 with an updated~~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 ~~years 2022 through 2028, which included additional information as required by~~ultimate outcome of this proceeding and the PURA. As required, the plan includes a full deployment of advanced metering functionality and a composite business case in support of the Advanced Metering Infrastructure plan. The procedural schedule includes briefs that were filed on April 29, 2022 and written comments that were filed July 20, 2022.resulting impact to CL&P.

Aquarion Water Company of Connecticut Distribution ~~Rates:~~Rate Case: On ~~July 1,~~August 29, 2022, Aquarion Water Company of Connecticut (AWC-CT) filed ~~a letter of intent~~an application with PURA ~~that it intends to file an application~~ to amend its existing rate schedules to address an operating revenue deficiency. AWC-CT’s rate application ~~will request~~requested approval of rate increases of ~~$27.6~~$27.5 million, an additional ~~$15.3~~$13.6 million, and an additional ~~$9.9~~$8.8 million, effective ~~February~~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 ~~expects~~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 ~~file its rate application within 60 days from~~stay until further order and pending a hearing, which is scheduled in the ~~date~~second quarter of ~~the letter.~~2023.

~~Massachusetts:~~New Hampshire:

~~NSTAR Electric Distribution Rate Case~~PSNH Pole Acquisition Approval:: On ~~January 14,~~November 18, 2022, ~~NSTAR Electric filed an application~~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 DPU for approval of an $89 million increase in base distribution rates, with new rates anticipated to be effective January 1, 2023. On June 24, 2022, NSTAR Electric updated its requested increase to $94 million. As part of this filing, NSTAR Electric is requesting a renewaloperation and maintenance of the ~~performance-based ratemaking plan originally authorized in its last rate case for up to~~transferred poles, pole inspections, and vegetation management expenses through a ~~ten-year term, alignment with state electrification policy, storm fund refinements, and Advanced Metering Infrastructure tariff approval. A final decision from the DPU is expected on December 1, 2022.~~

~~NSTAR Electric Grid Modernization and Advanced Metering Infrastructure Filing:~~ On July 1, 2021, NSTAR Electric submitted for DPU approval its four-year $198.8 million grid modernization plan for the years 2022 through 2025 and proposed $620 million Advanced Metering Infrastructure investment and implementation plan (including program operating costs) for the years 2022 through 2028. As required, the plan includes a ten-year vision, five-year strategic plan, including a full deployment of advanced metering functionality, separate four-year grid-facing and customer-facing short-term investment plans, and a composite business case in support of the Advanced Metering Infrastructure plan. Reply briefs were filed by NSTAR Electric on June 27, 2022. NSTAR Electric expects DPU guidance for all investments by the fourth quarter of 2022. For Advanced Metering Infrastructure investments, additional review of thenew cost recovery mechanism, ~~will be conducted in NSTAR Electric’s base distribution rate case that was filed on January 14, 2022 with a decision expected on December 1, 2022.~~

~~Legislative:~~

~~Massachusetts:~~ ~~On July 31, 2022,~~ the ~~Massachusetts Legislature approved climate-related legislation in House Bill 5060, “An Act driving clean energy and offshore wind.” The Act, among other things, affirms the state’s commitment~~Pole Plant Adjustment Mechanism (PPAM), subject to contract for 5,600 MW of offshore wind by June 30, 2027, modifies the bidding process to encourage more competition among offshore wind developers, and provides incentives to increase the manufacturing and assembly of offshore wind components in Massachusetts. The Act also provides incentives to encourage the sale and leasing of electric vehicles, promotes energy storage and electrification technologies, directs electric companies to develop grid modernization plans to upgrade distribution and transmission facilities, and initiates a pilot program that would allow up to ten communities in the state to restrict fossil fuel use in new buildings. Additionally, for long-term contracts that are approved by the DPU between developers of offshore wind generation and the contracting electric distribution company, the Act provides for an annual remuneration for the distribution company equal to 2.25 per centconsummation of the ~~annual payments under the contract to compensate the distribution company~~purchase agreement. The purchase agreement was finalized on May 1, 2023 for ~~accepting the financial obligation~~a purchase price of ~~the long-term contract. Governor Baker has until August 11, 2022 to sign or veto the Act.~~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 ~~2021~~2022 Form 10-K. There have been no material changes with regard to these critical accounting policies.

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 ~~and six~~ months ended ~~June 30,~~March 31, 2023 and 2022 ~~and 2021~~ included in this combined Quarterly Report on Form 10-Q:


		For the Three Months Ended June 30,						For the Six Months Ended June 30,							For the Three Months Ended March 31,
(Millions of Dollars)	(Millions of Dollars)	2022		2021		Increase		2022		2021		Increase		(Millions of Dollars)		2023		2022		Increase/(Decrease)
Operating Revenues	Operating Revenues	$	2,572.6	$	2,122.5	$	450.1	$	6,044.0	$	4,948.4	$	1,095.6	Operating Revenues		$	3,795.6	$	3,471.3	$	324.3
Operating Expenses:	Operating Expenses:													Operating Expenses:
Purchased Power, Fuel and Transmission		940.5		650.1		290.4		2,330.2		1,648.6		681.6
Purchased Power, Purchased Natural Gas and Transmission														Purchased Power, Purchased Natural Gas and Transmission		1,903.2		1,389.7		513.5
Operations and Maintenance	Operations and Maintenance	452.2		411.1		41.1		924.6		876.7		47.9		Operations and Maintenance		454.6		472.4		(17.8)
Depreciation	Depreciation	294.2		274.6		19.6		583.6		545.4		38.2		Depreciation		313.0		289.3		23.7
Amortization	Amortization	70.4		5.6		64.8		307.4		113.6		193.8		Amortization		(76.1)		236.9		(313.0)
Energy Efficiency Programs	Energy Efficiency Programs	136.7		129.0		7.7		336.2		317.0		19.2		Energy Efficiency Programs		222.9		199.5		23.4
Taxes Other Than Income Taxes	Taxes Other Than Income Taxes	223.0		200.5		22.5		443.4		409.9		33.5		Taxes Other Than Income Taxes		228.4		220.4		8.0

Total Operating Expenses	Total Operating Expenses	2,117.0		1,670.9		446.1		4,925.4		3,911.2		1,014.2		Total Operating Expenses		3,046.0		2,808.2		237.8
Operating Income	Operating Income	455.6		451.6		4.0		1,118.6		1,037.2		81.4		Operating Income		749.6		663.1		86.5
Interest Expense	Interest Expense	160.1		145.4		14.7		313.3		283.1		30.2		Interest Expense		194.5		153.3		41.2
Other Income, Net	Other Income, Net	93.9		46.6		47.3		165.4		80.8		84.6		Other Income, Net		89.0		71.6		17.4
Income Before Income Tax Expense	Income Before Income Tax Expense	389.4		352.8		36.6		970.7		834.9		135.8		Income Before Income Tax Expense		644.1		581.4		62.7
Income Tax Expense	Income Tax Expense	95.6		86.4		9.2		231.6		200.4		31.2		Income Tax Expense		151.0		136.1		14.9
Net Income	Net Income	293.8		266.4		27.4		739.1		634.5		104.6		Net Income		493.1		445.3		47.8
Net Income Attributable to Noncontrolling Interests	Net Income Attributable to Noncontrolling Interests	1.9		1.9		—		3.8		3.8		—		Net Income Attributable to Noncontrolling Interests		1.9		1.9		—
Net Income Attributable to Common Shareholders	Net Income Attributable to Common Shareholders	$	291.9	$	264.5	$	27.4	$	735.3	$	630.7	$	104.6	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							Electric								Firm Natural Gas								Water
		Sales Volumes (GWh)		Percentage Decrease				Sales Volumes (MMcf)				Percentage Increase				Sales Volumes (MG)				Percentage Increase/(Decrease)			Sales Volumes (GWh)					Percentage Decrease			Sales Volumes (MMcf)					Percentage Decrease			Sales Volumes (MG)			Percentage (Decrease)/Increase
Three Months Ended June 30:		2022	2021			2022			2021					2022			2021
Three Months Ended March 31:																						Three Months Ended March 31:	2023				2022			Percentage Decrease		2023			2022				Percentage Decrease	2023		2022		Percentage (Decrease)/Increase

Traditional	Traditional	1,795	1,853			(3.1)	%		—		—			—	%		346		311					11.3	%	Traditional	1,900	1,992				(4.6)	%		—			—		—	%	313			324	(3.4)	%
Decoupled and Special Contracts (1)	Decoupled and Special Contracts (1)	9,840	10,142	(3.0)	%			24,894		24,790		0.4	%			5,244		5,530		(5.2)	%	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	Total Sales Volumes	11,635	11,995	(3.0)	%			24,894		24,790		0.4	%			5,590		5,841		(4.3)	%	Total Sales Volumes	12,198				12,965	(5.9)	%		59,783			68,518		(12.7)	%		4,905	4,666		5.1	%

Six Months Ended June 30:
Traditional		3,787	3,804	(0.4)	%			—		—		—	%			670		570		17.5	%
Decoupled and Special Contracts (1)		20,813	20,874	(0.3)	%			93,413		90,792		2.9	%			9,586		10,007		(4.2)	%
Total Sales Volumes		24,600	24,678	(0.3)	%			93,413		90,792		2.9	%			10,256		10,577		(3.0)	%

(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.

Operating Revenues: Operating Revenues by segment increased for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, as follows:

(Millions of Dollars) Three Months Ended Six Months Ended
Electric Distribution $ 327.9 $ 813.8
Natural Gas Distribution 104.4 251.5
Electric Transmission 46.4 80.9
Water Distribution 1.8 3.9
Other 5.7 46.3
Eliminations (36.1) (100.8)
Total Operating Revenues $ 450.1 $ 1,095.6


(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 ~~(excluding EGMA)~~ Distribution Revenues:

Base Distribution Revenues:

•Base electric distribution revenues increased ~~$18.7 million and $28.4~~$28.9 million for the three ~~and six~~ months ended ~~June 30,~~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 ~~2021,~~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 ~~Electric effective January 1, 2022 resulting from its annual Performance Based Rate Adjustment filing~~Gas and ~~at PSNH effective August 1, 2021 to reflect plant additions in calendar year 2020 included in its revenue requirement, partially offset by lower sales volumes at PSNH.~~

•Base natural gas distribution revenues (excluding EGMA) increased $3.8 million and $13.5 million for the three and six months ended June 30, 2022, as compared to the same periods in 2021, due primarily to a base distribution rate increase at NSTAR GasEGMA effective November 1, ~~2021.~~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 ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, due primarily to the following:


		Electric Distribution				Natural Gas Distribution					Electric Distribution		Natural Gas Distribution
(Millions of Dollars)	(Millions of Dollars)	Three Months Ended		Six Months Ended		Three Months Ended		Six Months Ended		(Millions of Dollars)	Three Months Ended		Three Months Ended
Retail Tariff Tracked Revenues:	Retail Tariff Tracked Revenues:									Retail Tariff Tracked Revenues:
Energy supply procurement	Energy supply procurement	$	146.4	$	311.4	$	26.7	$	68.8	Energy supply procurement	$	475.1	$	63.9
CL&P FMCC										CL&P FMCC	(139.3)		—
Retail transmission	Retail transmission	60.9		158.6		—		—		Retail transmission	(19.3)		—
Stranded costs		(23.2)		(44.5)		—		—
Energy efficiency										Energy efficiency	10.0		18.4
Other distribution tracking mechanisms	Other distribution tracking mechanisms	14.3		31.7		10.2		10.6		Other distribution tracking mechanisms	(3.7)		10.3
Wholesale Market Sales Revenue	Wholesale Market Sales Revenue	115.4		331.8		11.2		13.7		Wholesale Market Sales Revenue	(148.2)		15.6

The increase in energy supply procurement within ~~both~~ electric distribution and natural gas distribution for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, was driven ~~primarily~~ by higher average prices, ~~and higher~~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, ~~Fuel~~Purchased Natural Gas and Transmission Expense" below.

The ~~increase~~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 ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, was due primarily to ~~higher~~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 ~~increased approximately 131 and 133 percent~~decreased to an average price of $48.95 per MWh for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to $105.35 per MWh for the ~~same periods in 2021,~~three months ended March 31, 2022, driven primarily by ~~higher~~lower natural gas prices in New England.~~The increase in both periods was also due tohigher wholesale sales at CL&P resulting from the sale of output generated by the Seabrook PPA beginning in the first quarter of 2022.~~ 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.

The increase in electric distribution wholesale market sales revenues in both periods was also driven by higher proceeds from a one-year sale of transmission rights, effective June 2021, under CL&P’s, NSTAR Electric’s and PSNH’s Hydro-Quebec transmission support agreements. Proceeds from these sales are credited back to customers.

~~EGMA Natural Gas Distribution Revenues:~~ EGMA total operating revenues at the natural gas distribution segment increased by $52.0 million and $143.5 million for the three and six months ended June 30, 2022, as compared to the same periods in 2021. Included in the total operating revenues increase was EGMA’s base natural gas distribution revenues increase of $4.3 million and $22.1 million for the three and six months ended June 30, 2022, as compared to the same periods in 2021, due primarily to a base distribution rate increase effective November 1, 2021.

Electric Transmission Revenues: Electric transmission revenues increased ~~$46.4 million and $80.9~~$23.4 million for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~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, ~~Fuel~~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, ~~Fuel~~Purchased Natural Gas and Transmission expense increased for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, due primarily to the following:

(Millions of Dollars) Three Months Ended Six Months Ended
Purchased Power Costs $ 164.2 $ 385.2
Natural Gas Costs 83.8 180.5
Transmission Costs 66.4 166.8
Eliminations (24.0) (50.9)
Total Purchased Power, Fuel and Transmission $ 290.4 $ 681.6


(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 ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, was driven primarily by higher energy supply procurement costs resulting from higher average prices, ~~and higher~~partially offset by lower average supply-related sales volumes. The increase ~~in both periods~~ 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 ~~CL&P.~~

lower net metering costs at NSTAR Electric.

The increase in costs at the natural gas distribution segment for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, was due primarily to higher average prices, ~~and higher~~partially offset by lower average supply-related sales volumes.

The ~~increase~~decrease in transmission costs for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, was primarily the result of ~~an increase~~a decrease in costs billed by ISO-NE that support regional grid ~~investments and an increase resulting from the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.~~investments. This decrease was partially offset by ~~a decrease~~an increase in Local Network Service charges, which ~~reflects~~reflect the cost of transmission service provided by Eversource over our local transmission ~~network.~~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.

Operations and Maintenance expense includes tracked costs and costs that are part of base electric, natural gas and water distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense ~~increased~~decreased for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, due primarily to the following:

(Millions of Dollars) Three Months Ended Six Months Ended
Base Electric Distribution (Non-Tracked Costs):
   Absence in 2022 of CL&P charge for Tropical Storm Isaias response in 2021 $ 1.4 $ (28.6)
Storm costs (3.5) 4.5
Employee-related expenses, including labor and benefits 7.4 1.0
Operations-related expenses, including vehicles, vegetation management and outside services 3.4 —
Shared corporate costs (including computer software depreciation at Eversource Service) 5.7 9.8
Other non-tracked operations and maintenance 5.3 13.2
Total Base Electric Distribution (Non-Tracked Costs) 19.7 (0.1)
Tracked Electric Costs (Electric Distribution and Electric Transmission) - Increases due primarily to
  higher transmission expenses 19.9 39.3
Natural Gas Distribution:
Base (Non-Tracked Costs) - Increases due primarily to higher employee-related expenses and
  higher shared corporate costs 12.0 18.1
Tracked Costs 2.7 7.6
Total Natural Gas Distribution 14.7 25.7
Water Distribution 1.1 2.7
Parent and Other Companies and eliminations:
Eversource Parent and Other Companies - other operations and maintenance (4.6) 28.6
Transaction and Transition Costs (1.8) (3.1)
Eliminations (7.9) (45.2)
Total Operations and Maintenance $ 41.1 $ 47.9


(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~~expense increased for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, due primarily to higher utility plant in service ~~balances.~~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 supply,~~ 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. ~~Energy supply and energy-related~~These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of ~~certain~~certain costs as those costs are collected in rates.

~~Amortization increased~~Amortization decreased for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~ 2022, due primarily to the deferral adjustment of ~~energy supply,~~ 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 ~~increase~~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 ~~a decrease in storm amortization expense at CL&P related to the completion of~~ the amortization ~~period~~ of ~~certain storm costs deferred assets.~~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~~for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~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~~expense increased for ~~the~~the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, due primarily to ~~an increase in property taxes as a result of higher utility plant balances and~~ higher Connecticut gross earnings ~~taxes.~~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 ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, due primarily to an increase inin interest on long-term debt as a result of new debt issuances ($~~16.9 million and $28.4 million, respectively)~~44.6 million), an increase in interest on short-term notes payable ($~~2.9 million and $3.1 million, respectively)~~14.1 million), ~~and~~ an increase in interest expense on regulatory deferrals ~~for the six month period~~ ($~~2.7~~2.6 million)~~. These increases in interest expense were~~, 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~~million) and ~~$2.6 million, respectively),~~ a decrease inin RRB interest expense ($0.3 ~~million and $0.7 million, respectively) and a decrease in interest expense on regulatory deferrals for the three month period ($1.7~~ million).

Other Income, Net increased for the three ~~and six~~ months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same ~~periods~~period in ~~2021,~~2022, due primarily to an increase in interest income primarily from regulatory deferrals ($16.4 million), an increase in capitalized AFUDC related to ~~pension, SERP~~equity funds ($5.6 million), and ~~PBOP non-service income components ($32.8 million and $67.0 million, respectively),~~ an increase in equity in earnings related to Eversource's equity method investments ($~~11.9 million and $8.7 million, respectively)~~3.4 million), ~~an increase in interest income primarily from regulatory deferrals ($1.1 million and $6.2 million, respectively), and an increase in capitalized AFUDC~~partially offset by a decrease related to ~~equity funds~~pension, SERP and PBOP non-service income components ($~~2.0 million~~19.5 million) and ~~$2.7 million, respectively)~~higher investment losses driven by market volatility ($1.5 million).

Income Tax Expense increased for the three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to higher pre-tax earnings ($~~7.7 million), higher state taxes ($2.3~~13.2 million), lower share-based payment excess tax benefits ($~~0.1~~2.6 million), a decrease in amortization of EDIT ($1.5 million), and an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($~~3.4~~1.6 million), partially offset by ~~an increase in amortization of EDIT ($4.3 million).~~

~~Income Tax Expense~~ ~~increased for the six months ended June 30, 2022, as compared to the same period in 2021, due primarily to higher pre-tax earnings ($28.5 million), higher~~lower state taxes ($9.5 million), lower share-based payment excess tax benefits ($1.9 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 ($0.3 million), the absence in 2022 of a valuation allowance increase in 2021 ($1.7 million), and an increase in amortization of EDIT ($6.74.0 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 ~~six~~three months ended ~~June 30,~~March 31, 2023 and 2022 ~~and 2021~~ included in this combined Quarterly Report on Form 10-Q:


		For the Six Months Ended June 30,																			For the Three Months Ended March 31,
		CL&P						NSTAR Electric						PSNH							CL&P						NSTAR Electric						PSNH
(Millions of Dollars)	(Millions of Dollars)	2022		2021		Increase/ (Decrease)		2022		2021		Increase/ (Decrease)		2022		2021		Increase/ (Decrease)		(Millions of Dollars)	2023		2022		Increase/ (Decrease)		2023		2022		Increase/ (Decrease)		2023		2022		Increase/ (Decrease)
Operating Revenues	Operating Revenues	$	2,321.5	$	1,816.9	$	504.6	$	1,646.8	$	1,424.4	$	222.4	$	646.5	$	572.3	$	74.2	Operating Revenues	$	1,338.9	$	1,285.8	$	53.1	$	956.3	$	863.2	$	93.1	$	420.2	$	339.4	$	80.8
Operating Expenses:	Operating Expenses:																			Operating Expenses:
Purchased Power and Transmission	Purchased Power and Transmission	944.5		681.4		263.1		550.5		417.6		132.9		236.6		172.1		64.5		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	Operations and Maintenance	326.1		327.8		(1.7)		314.0		279.6		34.4		126.3		111.2		15.1		Operations and Maintenance	160.3		157.1		3.2		166.1		164.9		1.2		67.8		59.6		8.2
Depreciation	Depreciation	175.5		167.8		7.7		178.7		166.7		12.0		62.8		59.3		3.5		Depreciation	92.2		87.3		4.9		90.5		89.0		1.5		34.1		31.3		2.8
Amortization of Regulatory Assets, Net		212.5		47.7		164.8		49.4		15.9		33.5		36.1		44.8		(8.7)
Amortization of Regulatory (Liabilities)/Assets, Net																				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	Energy Efficiency Programs	65.2		65.1		0.1		149.5		139.4		10.1		17.5		19.7		(2.2)		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	Taxes Other Than Income Taxes	186.1		175.3		10.8		120.7		108.7		12.0		48.1		45.7		2.4		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	Total Operating Expenses	1,909.9		1,465.1		444.8		1,362.8		1,127.9		234.9		527.4		452.8		74.6		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	Operating Income	411.6		351.8		59.8		284.0		296.5		(12.5)		119.1		119.5		(0.4)		Operating Income	223.9		222.5		1.4		176.3		126.2		50.1		64.6		64.4		0.2
Interest Expense	Interest Expense	82.8		81.6		1.2		77.1		69.5		7.6		28.4		28.4		—		Interest Expense	45.2		40.6		4.6		44.9		38.2		6.7		17.5		13.6		3.9
Other Income, Net	Other Income, Net	39.4		14.8		24.6		63.5		38.7		24.8		15.3		8.4		6.9		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	Income Before Income Tax Expense	368.2		285.0		83.2		270.4		265.7		4.7		106.0		99.5		6.5		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	Income Tax Expense	89.4		71.0		18.4		58.2		60.9		(2.7)		23.4		20.2		3.2		Income Tax Expense	45.2		48.5		(3.3)		37.5		24.5		13.0		12.5		12.7		(0.2)
Net Income	Net Income	$	278.8	$	214.0	$	64.8	$	212.2	$	204.8	$	7.4	$	82.6	$	79.3	$	3.3	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 Six Months Ended June 30,		For the Three Months Ended March 31,
		2022	2021		Percentage Decrease			2023	2022	Percentage Decrease
CL&P	CL&P	9,919	9,952		(0.3)	%	CL&P	4,802	5,263	(8.8)	%
NSTAR Electric	NSTAR Electric	10,894	10,922		(0.3)	%	NSTAR Electric	5,496	5,710	(3.7)	%
PSNH	PSNH	3,787	3,804		(0.4)	%	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 ~~$504.6~~$53.1 million at CL&P, ~~$222.4~~$93.1 million at NSTAR Electric, and ~~$74.2~~$80.8 million at PSNH, for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021.~~2022.

5549

Base Distribution Revenues:

•CL&P's distribution revenues ~~increased $0.4 million.~~were flat.

•NSTAR Electric's distribution revenues increased ~~$26.6~~$30.6 million due primarily to the ~~impact~~result of ~~its~~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 ~~from its~~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 ~~Performance Based Rate Adjustment filing.~~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 ~~increased $1.4~~decreased $1.7 million due primarily to a decrease in sales volumes as a result of milder winter weather in the ~~impact~~first quarter of ~~its base distribution rate increase effective August 1, 2021~~2023, as compared to ~~reflect plant additions~~the same period in ~~calendar year 2020 included in its revenue requirement, partially offset by lower sales volumes.~~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.

Tracked distribution revenues increased/(decreased) for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:


(Millions of Dollars)	(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		(Millions of Dollars)	CL&P		NSTAR Electric		PSNH
Retail Tariff Tracked Revenues:	Retail Tariff Tracked Revenues:							Retail Tariff Tracked Revenues:
Energy supply procurement	Energy supply procurement	$	198.0	$	35.8	$	77.6	Energy supply procurement	$	296.5	$	93.3	$	85.3
CL&P FMCC								CL&P FMCC	(139.3)		—		—
Retail transmission	Retail transmission	63.3		94.6		0.7		Retail transmission	8.1		(13.2)		(14.2)
Stranded costs		(7.1)		(7.2)		(30.2)
Other distribution tracking mechanisms	Other distribution tracking mechanisms	15.5		18.3		(2.1)		Other distribution tracking mechanisms	3.3		0.9		2.1
Wholesale Market Sales Revenue	Wholesale Market Sales Revenue	245.6		62.2		24.0		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 ~~primarily by higher average prices and higher average supply-related sales volumes. The increase in energy supply procurement at NSTAR Electric was driven primarily~~ by higher average prices, partially offset by lower average supply-related sales volumes.

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 ~~higher~~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 ~~increased approximately 133 percent~~decreased to an average price of $48.95 per MWh for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to $105.35 per MWh for the ~~same period in 2021,~~three months ended March 31, 2022, driven primarily by ~~higher~~lower natural gas prices in New England.~~The increase was also due tohigher wholesale sales at~~ CL~~&P resulting from the sale of output generated by the Seabrook PPA beginning in the first quarter of 2022.~~ ~~Volumes~~&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.

The increase in wholesale market sales revenues at CL&P, NSTAR Electric and PSNH was also driven by higher proceeds from a one-year sale of transmission rights, effective June 2021, under CL&P’s, NSTAR Electric’s and PSNH’s Hydro-Quebec transmission support agreements. Proceeds from these sales are credited back to customers.

Transmission Revenues: Transmission revenues increased ~~$33.1~~$3.7 million at CL&P, ~~$29.6~~$6.3 million at NSTAR Electric, and ~~$18.2~~$13.4 million at PSNH for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~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 ~~decreased~~increased revenues by ~~$41.8~~$6.0 million at CL&P ~~$37.4~~and $1.8 million at PSNH and decreased revenues by $5.8 million at NSTAR Electric ~~and $14.7 million at PSNH~~ for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021.~~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 ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:


(Millions of Dollars)	(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		(Millions of Dollars)	CL&P		NSTAR Electric		PSNH
Purchased Power Costs	Purchased Power Costs	$	236.0	$	75.5	$	73.7	Purchased Power Costs	$	305.5	$	66.3	$	108.1
Transmission Costs	Transmission Costs	66.7		94.7		5.4		Transmission Costs	15.4		(13.2)		(9.0)
Eliminations	Eliminations	(39.6)		(37.3)		(14.6)		Eliminations	6.2		(5.9)		1.8
Total Purchased Power and Transmission	Total Purchased Power and Transmission	$	263.1	$	132.9	$	64.5	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, ~~and higher~~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. ~~The increase~~This was ~~also due to higher~~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, ~~and higher average supply-related sales volumes,~~ partially offset by lower stranded costs resulting from higher Regional Greenhouse Gas Initiative (RGGI) proceeds received, which are credited back to customers. The higher RGGI proceeds resulted from an increase in RGGI auction clearing prices for allowances in the six months ended June 30, 2022, as compared to the same period in 2021.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 ~~NSTAR Electric and PSNH~~ was due primarily to ~~an increase in costs billed by ISO-NE that support regional grid investments and~~ 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 ~~(decreased)/~~increased for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:


(Millions of Dollars)	(Millions of Dollars)	CL&P		NSTAR Electric		PSNH		(Millions of Dollars)	CL&P		NSTAR Electric		PSNH
Base Electric Distribution (Non-Tracked Costs):	Base Electric Distribution (Non-Tracked Costs):							Base Electric Distribution (Non-Tracked Costs):
Absence in 2022 of CL&P charge for Tropical Storm Isaias response in 2021		$	(28.6)	$	—	$	—
Storm costs		(1.2)		2.8		2.9
Employee-related expenses, including labor and benefits		7.0		(1.1)		3.7
Operations-related expenses, including employee-related costs, vehicles, vegetation management and outside services		2.7		(3.6)		0.9
Operations-related expenses (including employee-related expenses, storm costs, vendor services, and vehicles)								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)	Shared corporate costs (including computer software depreciation at Eversource Service)	3.4		5.2		1.2		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)								General costs (including vendor services in corporate areas, insurance, fees and assessments)	2.6		3.3		1.2
Vegetation management								Vegetation management	(5.0)		0.9		(1.2)
Other non-tracked operations and maintenance	Other non-tracked operations and maintenance	2.9		8.6		1.7		Other non-tracked operations and maintenance	(2.3)		(5.3)		(0.3)
Total Base Electric Distribution (Non-Tracked Costs)	Total Base Electric Distribution (Non-Tracked Costs)	(13.8)		11.9		10.4		Total Base Electric Distribution (Non-Tracked Costs)	2.7		4.4		4.4
Tracked Costs:	Tracked Costs:							Tracked Costs:
Transmission expenses	Transmission expenses	8.7		5.4		5.5		Transmission expenses	(1.6)		(0.7)		2.7
Other tracked operations and maintenance	Other tracked operations and maintenance	3.4		17.1		(0.8)		Other tracked operations and maintenance	2.1		(2.5)		1.1
Total Tracked Costs	Total Tracked Costs	12.1		22.5		4.7		Total Tracked Costs	0.5		(3.2)		3.8
Total Operations and Maintenance	Total Operations and Maintenance	$	(1.7)	$	34.4	$	15.1	Total Operations and Maintenance	$	3.2	$	1.2	$	8.2

Depreciationexpense increased ~~for~~for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~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 supply,~~ 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. ~~Energy supply and energy-related~~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 ~~increased/~~decreased for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:

•The ~~increase~~decrease at CL&P was due primarily to the deferral adjustment of ~~energy supply,~~ 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 ~~increase~~decrease in the FMCC mechanism was ~~partially offset~~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 ~~in storm~~to amortization expense ~~related~~of $286.6 million in the first quarter of 2023, as compared to the ~~completion~~first quarter of ~~the amortization period of certain storm cost deferred assets.~~2022.

•The ~~increase~~decrease at NSTAR Electric was due to the deferral adjustment of ~~energy supply,~~ energy-related costs and other tracked ~~costs.~~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 ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:

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

Taxes Other Than Income Taxes ~~increased~~increased/decreased for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:

•The increase at CL&P was related to higher ~~property taxes as a result of a higher utility plant balance and higher~~ gross earnings taxes.

•The ~~increases~~decreases at NSTAR Electric and PSNH were due primarily to ~~higher~~a decrease in property taxes ~~as a result of higher utility plant balances.~~due to lower mill rates.

Interest Expense increased for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:

•The increase at CL&P was due to higher interest on long-term debt ($~~1.7 million) and higher amortization of debt discounts and premiums, net ($0.3~~3.8 million), ~~partially offset by lower~~an increase in interest expense on regulatory deferrals ($~~1.0~~0.9 million), and higher interest on short-term notes payable ($0.6 million), partially offset by an increase in capitalized AFUDC related to debt funds ($~~0.4~~0.7 million).

•The increase at NSTAR Electric was due to higher interest on long-term debt ($~~5.2~~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 ($3.4 million), higher interest expense on regulatory deferrals ($~~2.8~~0.9 million), and ~~a decrease~~higher interest on short-term notes payable ($0.2 million), partially offset by an increase in capitalized AFUDC related to debt funds ($~~0.4~~0.5 million) and a decrease in RRB interest expense ($0.3 million).

Other Income, Net ~~increased~~increased/decreased for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:

•The ~~increase~~decrease at CL&P was due primarily to ~~an increase~~a decrease related to pension, SERP and PBOP non-service income components ($~~25.1~~6.4 million) and higher investment losses driven by market volatility ($0.2 million), partially offset by an increase in capitalized AFUDC related to equity funds ($~~2.2~~1.3 million)~~, partially offset by investment losses~~ and an increase in ~~2022 compared to investment~~interest income ~~in 2021 driven by market volatility~~primarily on regulatory deferrals ($~~2.6~~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 ($4.6 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($~~22.2~~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 ($0.3 million), partially offset by an increase in interest income primarily on regulatory deferrals ($~~4.7~~0.6 million)~~, partially offset by a decrease~~ and an increase in capitalized AFUDC related to equity funds ($~~1.4 million) and lower investment income ($0.6 million).~~

•The increase at PSNH was due primarily to an increase related to pension, SERP and PBOP non-service income components ($7.9 million), partially offset by a decrease in interest income primarily on regulatory deferrals ($0.90.3 million).

Income Tax Expense increased/decreased for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to the following:

•The ~~increase~~decrease at CL&P was due primarily to ~~higher~~lower pre-tax earnings ($~~17.5~~1.7 million), ~~higher~~lower state taxes ($~~3.6~~1.4 million), ~~and a decrease~~an increase in amortization of EDIT ($~~0.7 million), partially offset by the absence in 2022 of a valuation allowance increase in 2021 ($1.7~~0.2 million), and a decrease in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($~~1.7~~0.9 million), partially offset by lower share-based payment excess tax benefits ($0.9 million).

•The ~~decrease~~increase at NSTAR Electric was due primarily to an increase in ~~amortization of EDIT ($6.5 million), partially offset by an increase in~~ pre-tax earnings ($~~1.0~~11.4 million), higher state taxes ($~~0.6~~3.0 million), lower share-based payment excess tax benefits ($~~0.6~~1.0 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).~~

•~~The increase at PSNH was due primarily to higher pre-tax earnings ($1.4 million), higher state taxes ($1.2 million),~~ a decrease in amortization of EDIT ($~~0.8~~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 ($~~0.2~~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 ~~increased $64.8~~decreased $4.6 million for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to ~~the absence in 2022 of the $28.6 million pre-tax charge 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 ~~for the storm performance penalty imposed by PURA as a result of CL&P’s preparation for and response to Tropical Storm Isaias in August 2020 that~~decrease was ~~recorded in 2021. The after-tax impact of the storm performance penalty was $22.6 million. Earnings were also favorably impacted~~partially offset by higher earnings from its capital tracking mechanism due to increased electric system ~~improvements,~~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, ~~and lower pension plan expense. The earnings increase was~~ partially offset by higher operations and maintenance ~~expense, higher depreciation, and higher property and other tax~~ expense.

~~NSTAR Electric's~~PSNH's earnings ~~increased $7.4~~decreased $5.3 million for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to the same period in ~~2021,~~2022, due primarily to ~~the base distribution rate increase effective January 1, 2022~~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. ~~The earnings increase was partially offset by higher operations and maintenance expense, higher interest expense, higher depreciation expense, and higher property and other tax expense.~~

PSNH's earnings increased $3.3 million for the six months ended June 30, 2022, as compared to the same period in 2021, due primarily to an increase in transmission earnings driven by a higher transmission rate base and lower pension plan expense. The earnings increase was partially offset by higher operations and maintenance expense, the absence in 2022 of a favorable impact of a new tracker mechanism at PSNH approved as part of the 2020 rate settlement agreement that was recorded in 2021, and higher depreciation expense.

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 ~~$238.6 million for the six months ended June 30, 2022, as compared to $224.0~~$135.3 million in the same period of ~~2021.~~2022. The ~~increase~~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,~~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 ~~absence~~statement of cash flows. The impact of regulatory collections are included in ~~2022~~both Regulatory Recoveries and Amortization of ~~pension contributions~~Regulatory Liabilities/Assets on the statements of ~~$37.9 million made in 2021.~~cash flows. These ~~favorable~~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 ~~to CL&P’s customers~~ in ~~the first half of~~ 2022 as a result of the October 2021 settlement agreement and the 2021 storm performance penalty for ~~its~~CL&P’s response to Tropical Storm Isaias, an increase in regulatory under-recoveries (net of regulatory amortization) driven by an increase of $29.5 million in cash payments for storm costs and the timing of collections for regulatory tracking mechanisms, the timing of cash collections on our accounts receivable, a ~~$49.5~~$30.0 million increase in income tax ~~payments made~~refunds received in ~~2022,~~2023, as compared to ~~2021,~~2022, and the timing of other working capital items.

NSTAR Electric had cash flows provided by operating activities of ~~$197.1~~$140.8 million for the ~~six~~three months ended ~~June 30, 2022,~~March 31, 2023, as compared to ~~$245.9~~$189.9 million in the same period of ~~2021.~~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 ~~(net of regulatory amortization)~~ driven by ~~an increase in cash payments for storm costs and~~ 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 ~~$76.1~~$28.9 million ~~payment~~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 ~~second quarter~~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, ~~related to withheld property taxes,~~the timing of cash collections on our accounts receivable, and the timing of cash payments made on our accounts payable. These unfavorable impacts were partially offset by the timing of cash collections on our accounts receivable, a $16.6 million increase in income tax refunds received in 2022, as compared to 2021, and the timing of other working capital items.

PSNH had cash flows provided by operating activities of $140.4 million for the six months ended June 30, 2022, as compared to $138.3 million in the same period of 2021. The increase in operating cash flows was due primarily to the timing of cash payments made on our accounts payable and timing of collections for regulatory tracking mechanisms (net of regulatory amortization), partially offset by the timing of other working capital items and the timing of cash collections on our accounts receivable.

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

~~RESULTS OF OPERATIONS – THE CONNECTICUT LIGHT AND POWER COMPANY~~

The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P for the three months ended June 30, 2022 and 2021 included in this combined Quarterly Report on Form 10-Q:

For the Three Months Ended June 30,
(Millions of Dollars) 2022 2021 Increase/(Decrease)
Operating Revenues $ 1,035.7 $ 829.6 $ 206.1
Operating Expenses:
Purchased Power and Transmission 421.0 308.1 112.9
Operations and Maintenance 169.0 152.4 16.6
Depreciation 88.2 84.4 3.8
Amortization of Regulatory Assets/(Liabilities), Net 42.8 (15.1) 57.9
Energy Efficiency Programs 29.8 29.5 0.3
Taxes Other Than Income Taxes 95.8 84.0 11.8
Total Operating Expenses 846.6 643.3 203.3
Operating Income 189.1 186.3 2.8
Interest Expense 42.2 42.6 (0.4)
Other Income, Net 19.8 9.9 9.9
Income Before Income Tax Expense 166.7 153.6 13.1
Income Tax Expense 40.9 38.0 2.9
Net Income $ 125.8 $ 115.6 $ 10.2

~~Operating Revenues~~

~~Sales Volumes:~~ CL&P's retail electric GWh sales volumes were 4,656 and 4,797 for the three months ended June 30, 2022 and 2021, respectively, resulting in a decrease of 2.9 percent. Fluctuations in retail electric sales volumes do not impact earnings due to its PURA-approved distribution revenue decoupling mechanism.

~~Operating Revenues:~~ Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, increased $206.1 million for the three months ended June 30, 2022, as compared to the same period in 2021.

~~Base Distribution Revenues:~~ ~~CL&P's distribution revenues increased $0.1 million.~~

~~Tracked Revenues:~~ ~~Tracked revenues increased for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to the following:~~


~~(Millions of Dollars)~~
~~Retail Tariff Tracked Revenues:~~
~~Energy supply procurement~~	$	~~93.2~~
~~Retail transmission~~	~~34.6~~
~~Other distribution tracking mechanisms~~	~~5.9~~
~~Wholesale Market Sales Revenue~~	~~75.3~~

The increase in energy supply procurement was driven by higher average prices and higher 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 increase in electric distribution wholesale market sales revenue was due primarily to higher average electricity market prices received for wholesale sales. ISO-NE average market prices received for CL&P’s wholesale sales increased approximately 131 percent for the three months ended June 30, 2022, as compared to the same period in 2021, driven primarily by higher natural gas prices in New England.~~The increase was also due tohigher wholesale sales at CL&P resulting from the sale of output generated by the Seabrook PPA beginning in the first quarter of 2022.~~ Volumes sold into the market were primarily from the sale of output generated by the Millstone PPA and the 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 FMCC rate.

The increase in wholesale market sales revenues at CL&P was also driven by higher proceeds from a one-year sale of transmission rights, effective June 2021, under CL&P’s Hydro-Quebec transmission support agreements. Proceeds from these sales are credited back to customers.

~~Transmission Revenues:~~ ~~Transmission revenues increased $19.7 million due primarily to a higher transmission rate base as a result of continued investment in our transmission infrastructure.~~

~~Eliminations:~~ Eliminations are primarily related to transmission revenues derived from ISO-NE regional transmission charges to the distribution business that recover the costs of the wholesale transmission business. The impact of eliminations decreased revenues by $20.7 million.

~~Purchased Power and Transmission~~ expense includes costs associated with purchasing electricity on behalf of CL&P'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 PURA-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). Purchased Power and Transmission expense increased for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to the following:


~~(Millions of Dollars)~~
~~Purchased Power Costs~~	$	~~94.7~~
~~Transmission Costs~~	~~36.9~~
~~Eliminations~~	~~(18.7)~~
~~Total Purchased Power and Transmission~~	$	~~112.9~~

The increase at CL&P was due primarily to higher energy supply procurement costs resulting from higher average prices and higher average supply-related 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 in transmission costs was due primarily to an increase in costs billed by ISO-NE that support regional grid investments and 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 Local Network Service charges, which reflect the cost of transmission service provided over our local transmission network.

~~Operations and Maintenance~~ expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). Operations and Maintenance expense increased for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to the following:


~~(Millions of Dollars)~~
~~Base Electric Distribution (Non-Tracked Costs):~~

~~Employee-related expenses, including labor and benefits~~	$	~~6.3~~
~~Operations-related expenses, including vegetation management, vehicles and outside services~~	~~2.5~~
~~Storm costs~~	~~(2.0)~~
~~Other non-tracked operations and maintenance~~	~~4.2~~
~~Total Base Electric Distribution (Non-Tracked Costs)~~	~~11.0~~
~~Total Tracked Costs - Increase due primarily to higher transmission expenses~~	~~5.6~~
~~Total Operations and Maintenance~~	$	~~16.6~~

~~Depreciation~~ ~~expense increased for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to a higher net plant in service balance.~~

~~Amortization of Regulatory Assets, Net~~ expense includes the deferral of energy supply, energy-related costs and other costs that are included in certain regulatory-approved cost tracking mechanisms, and the amortization of certain costs as those costs are collected in rates. This deferral adjusts expense to match the corresponding revenues. Energy supply and energy-related costs are recovered from customers in rates and have no impact on earnings. Amortization of Regulatory Assets, Net increased for the three months ended June 30, 2022, as compared to the same period in 2021, due to the deferral adjustment of energy supply, 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 increase was partially offset by a decrease in storm amortization expense related to the completion of the amortization period of certain storm cost deferred assets.

~~Taxes Other Than Income Taxes~~ increased for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to higher property taxes as a result of a higher utility plant balance and higher gross earnings taxes.

~~Interest Expense~~ decreased for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to a decrease in interest expense on regulatory deferrals ($1.9 million), partially offset by higher interest on long-term debt ($0.8 million).

~~Other Income, Net~~ ~~increased for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to an increase related to pension, SERP and PBOP non-service income components ($11.9 million), partially offset by investment losses in 2022 compared to investment income in 2021 driven by market volatility ($1.9 million~~).

~~Income Tax Expense~~ ~~increased for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to higher pre-tax earnings ($2.7 million) and higher state taxes ($0.2 million).~~

~~EARNINGS SUMMARY~~

~~CL&P's earnings increased $10.2 million~~for the three months ended June 30, 2022, as compared to the same period in 2021, due primarily to higher earnings from its capital tracking mechanism due to increased electric system improvements, an increase in transmission earnings driven by a higher transmission rate base, and lower pension plan expense. The earnings increase was partially offset by higher operations and maintenance expense, higher property and other tax expense, and higher depreciation expense.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Market Risk Information

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

Other Risk Management Activities

Interest Rate Risk Management: We manage our interest rate risk exposure in accordance with our written policies and procedures 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 ~~June 30, 2022,~~March 31, 2023, our regulated companies held collateral (letters of credit or cash) of ~~$190.4~~$17.0 million from counterparties related to our standard service contracts. As of ~~June 30, 2022,~~March 31, 2023, Eversource had ~~$34.7~~$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 ~~2021~~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 ~~2021~~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 ~~June 30, 2022~~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 ~~June 30, 2022~~March 31, 2023 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.

6354

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 ~~2021~~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 ~~2021~~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 ~~2021~~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 ~~2021~~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)
April 1 - April 30, 2022 — $ — — —
May 1 - May 31, 2022 223 87.53 — —
June 1 - June 30, 2022 2,350 84.33 — —
Total 2,573 $ 84.60 — —


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	—	—

6455

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	~~Seventeenth~~Eighteenth Supplemental Indenture between Eversource Energy and The Bank of New York Trust Company, N.A., as Trustee, dated as of ~~June~~March 1, ~~2022,~~2023, relating to ~~(i) $900~~$750 million aggregate principal amount of its ~~4.20%~~5.45% Senior Notes, Series X,Z, Due ~~2024 and (ii) $600 million aggregate principal amount of its 4.60% Senior Notes, Series Y, Due 2027 (Exhibit~~2028 (Exhibit 4.1, Eversource Energy Current Report on Form 8-K filed ~~June 27, 2022,~~March 6, 2023, File No. ~~001-05324)~~001-05324

*	10	Equity Distribution Agreement, dated as of May 11, 2022, by and among Eversource Energy, Goldman Sachs & Co. LLC, Barclays Capital Inc., Citigroup Global Markets Inc., Wells Fargo Securities, LLC, Morgan Stanley & Co. LLC and J.P. Morgan Securities LLC (Exhibit 1.1, Eversource Energy Current Report on Form 8-K filed May 11, 2022, 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)
*	4	~~Form of 4.55% Debenture due June 1, 2052 (Exhibit 4.1, NSTAR Electric Company Current Report on Form 8-K filed on May 17, 2022, File No. 001-02301)~~

	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 ~~June 30, 2022,~~March 31, 2023, formatted in Inline XBRL

6656

SIGNATURE

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


	EVERSOURCE ENERGY

~~August 4, 2022~~May 5, 2023	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE


	THE CONNECTICUT LIGHT AND POWER COMPANY

~~August 4, 2022~~May 5, 2023	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE


	NSTAR ELECTRIC COMPANY

~~August 4, 2022~~May 5, 2023	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

SIGNATURE


	PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE

~~August 4, 2022~~May 5, 2023	By:	/s/ Jay S. Buth
		Jay S. Buth
		Vice President, Controller and Chief Accounting Officer

6757


	Shares
			Authorized as of June 30, 2022 and December 31, 2021	Issued as of
	Par Value			June 30, 2022	December 31, 2021
Eversource	$	5	380,000,000	359,211,206	357,818,402
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