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| 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, 2024
| or
☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
| For the transition period from ____________ to ____________

Registrant; State of Incorporation; Address; Telephone Number;
Commission File Number; and I.R.S. Employer Identification No.
EVERSOURCE ENERGY
(a Massachusetts voluntary association)
300 Cadwell Drive, Springfield, Massachusetts 01104
Telephone: (800) 286-5000
Commission File Number: 001-05324
I.R.S. Employer Identification No. 04-2147929
THE CONNECTICUT LIGHT AND POWER COMPANY
(a Connecticut corporation)
107 Selden Street, Berlin, Connecticut 06037-1616
Telephone: (800) 286-5000
Commission File Number: 000-00404
I.R.S. Employer Identification No. 06-0303850
NSTAR ELECTRIC COMPANY
(a Massachusetts corporation)
800 Boylston Street, Boston, Massachusetts 02199
Telephone: (800) 286-5000
Commission File Number: 001-02301
I.R.S. Employer Identification No. 04-1278810
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
(a New Hampshire corporation)
Energy Park
780 North Commercial Street, Manchester, New Hampshire 03101-1134
Telephone: (800) 286-5000
Commission File Number: 001-06392
I.R.S. Employer Identification No. 02-0181050

Securities registered pursuant to Section 12(b) of the Act:
Title of each class |  | Trading Symbol(s) |  | Name of each exchange on which registered
Common Shares, $5.00 par value per share |  | ES |  | New York Stock Exchange

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

| Yes | No
| ☒ | ☐

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

| Yes | No
| ☒ | ☐

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

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

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act):

| Yes | No
Eversource Energy | ☐ | ☒
The Connecticut Light and Power Company | ☐ | ☒
NSTAR Electric Company | ☐ | ☒
Public Service Company of New Hampshire | ☐ | ☒

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

Company - Class of Stock | Outstanding as of July 31, 2024
Eversource Energy Common Shares, $5.00 par value | 357,384,733 |  | 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.
The Connecticut Light and Power Company, 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

i

ESOP | Employee Stock Ownership Plan
Eversource 2023 Form 10-K | The Eversource Energy and Subsidiaries 2023 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
GSEP | Gas System Enhancement Program
GWh | Gigawatt-Hours
IPP | Independent Power Producers
ISO-NE Tariff | ISO-NE FERC Transmission, Markets and Services Tariff
kV | Kilovolt
kVa | Kilovolt-ampere
kW | Kilowatt (equal to one thousand watts)
LNG | Liquefied natural gas
LPG | Liquefied petroleum gas
LRS | Supplier of last resort service
MG | Million gallons
MGP | Manufactured Gas Plant
MMBtu | Million British thermal units
MMcf | Million cubic feet
Moody's | Moody's Investors Services, Inc.
MW | Megawatt
MWh | Megawatt-Hours
NETOs | New England Transmission Owners (including Eversource, National Grid and Avangrid)
OCI | Other Comprehensive Income/(Loss)
OREC | Offshore Wind Renewable Energy Certificate
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
PPAM | Pole Plant Adjustment Mechanism
RECs | Renewable Energy Certificates
Regulatory ROE | The average cost of capital method for calculating the return on equity related to the distribution business segment excluding the wholesale transmission segment
ROE | Return on Equity
RRBs | Rate Reduction Bonds or Rate Reduction Certificates
RSUs | Restricted share units
S&P | Standard & Poor's Financial Services LLC
SERP | Supplemental Executive Retirement Plans and non-qualified defined benefit retirement plans
SS | Standard service
UI | The United Illuminating Company
VIE | Variable Interest Entity

ii

EVERSOURCE ENERGY AND SUBSIDIARIES
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
TABLE OF CONTENTS

| Page
PART I – FINANCIAL INFORMATION
ITEM 1. | Financial Statements (Unaudited) |
| Eversource Energy and Subsidiaries (Unaudited) |
| Condensed Consolidated Balance Sheets | 1
| Condensed Consolidated Statements of Income | 2
| Condensed Consolidated Statements of Comprehensive Income | 2
| Condensed Consolidated Statements of Common Shareholders' Equity | 3
| Condensed Consolidated Statements of Cash Flows | 4
| The Connecticut Light and Power Company (Unaudited) |
| Condensed Balance Sheets | 5
| Condensed Statements of Income | 6
| Condensed Statements of Comprehensive Income | 6
| Condensed Statements of Common Stockholder's Equity | 7
| Condensed Statements of Cash Flows | 8
| NSTAR Electric Company and Subsidiary (Unaudited) |
| Condensed Consolidated Balance Sheets | 9
| Condensed Consolidated Statements of Income | 10
| Condensed Consolidated Statements of Comprehensive Income | 10
| Condensed Consolidated Statements of Common Stockholder's Equity | 11
| Condensed Consolidated Statements of Cash Flows | 12
| Public Service Company of New Hampshire and Subsidiaries (Unaudited) |
| Condensed Consolidated Balance Sheets | 13
| Condensed Consolidated Statements of Income | 14
| Condensed Consolidated Statements of Comprehensive Income | 14
| Condensed Consolidated Statements of Common Stockholder's Equity | 15
| Condensed Consolidated Statements of Cash Flows | 16
| Combined Notes to Condensed Financial Statements (Unaudited) | 17
ITEM 2. | Management's Discussion and Analysis of Financial Condition and Results of Operations |
| Eversource Energy and Subsidiaries | 39
| The Connecticut Light and Power Company, NSTAR Electric Company and Subsidiary, and Public Service Company of New Hampshire and Subsidiaries | 54
ITEM 3. | Quantitative and Qualitative Disclosures About Market Risk | 58
ITEM 4. | Controls and Procedures | 59
PART II – OTHER INFORMATION
ITEM 1. | Legal Proceedings | 59
ITEM 1A. | Risk Factors | 59
ITEM 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 59
ITEM 3. | Defaults Upon Senior Securities | 59
ITEM 4. | Mine Safety Disclosures | 59
ITEM 5. | Other Information | 59
ITEM 6. | Exhibits | 60
SIGNATURES | 61

iii

EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)

(Thousands of Dollars) | As of June 30, 2024 |  | As of December 31, 2023
ASSETS |  |  |
Current Assets: |  |  |
Cash | $ | 33,381 |  |  | $ | 53,873 |
Receivables, Net (net of allowance for uncollectible accounts of $579,582 and $554,455 as of June 30, 2024 and December 31, 2023, respectively) | 1,473,255 |  |  | 1,431,531 |
Unbilled Revenues | 196,710 |  |  | 225,325 |
Materials, Supplies, Natural Gas and REC Inventory | 532,415 |  |  | 507,307 |
Regulatory Assets | 2,071,652 |  |  | 1,674,196 |
Prepayments and Other Current Assets | 365,209 |  |  | 355,762 |
Total Current Assets | 4,672,622 |  |  | 4,247,994 |
Property, Plant and Equipment, Net | 41,126,153 |  |  | 39,498,607 |
Deferred Debits and Other Assets: |  |  |
Regulatory Assets | 4,995,989 |  |  | 4,714,970 |
Goodwill | 4,532,135 |  |  | 4,532,100 |
Investments in Unconsolidated Affiliates | 949,037 |  |  | 660,473 |
Prepaid Pension and PBOP | 1,101,017 |  |  | 1,028,207 |
Marketable Securities | 331,730 |  |  | 337,814 |
Other Long-Term Assets | 643,771 |  |  | 592,080 |
Total Deferred Debits and Other Assets | 12,553,679 |  |  | 11,865,644 |
Total Assets | $ | 58,352,454 |  |  | $ | 55,612,245 |
LIABILITIES AND CAPITALIZATION |  |  |
Current Liabilities: |  |  |
Notes Payable | $ | 1,401,600 |  |  | $ | 1,930,422 |
Long-Term Debt – Current Portion | 1,328,251 |  |  | 824,847 |
Rate Reduction Bonds – Current Portion | 43,210 |  |  | 43,210 |
Accounts Payable | 1,759,283 |  |  | 1,869,187 |
Accrued Interest | 327,814 |  |  | 260,577 |
Regulatory Liabilities | 652,291 |  |  | 591,750 |
Other Current Liabilities | 740,700 |  |  | 821,404 |
Total Current Liabilities | 6,253,149 |  |  | 6,341,397 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated Deferred Income Taxes | 5,249,786 |  |  | 5,303,730 |
Regulatory Liabilities | 4,092,811 |  |  | 4,022,923 |
Asset Retirement Obligations | 508,733 |  |  | 505,844 |
Accrued Pension, SERP and PBOP | 125,381 |  |  | 123,754 |
Other Long-Term Liabilities | 966,558 |  |  | 1,029,238 |
Total Deferred Credits and Other Liabilities | 10,943,269 |  |  | 10,985,489 |
Long-Term Debt | 25,836,078 |  |  | 23,588,616 |
Rate Reduction Bonds | 345,677 |  |  | 367,282 |
Noncontrolling Interest – Preferred Stock of Subsidiaries | 155,568 |  |  | 155,569 |
Common Shareholders' Equity: |  |  |
Common Shares | 1,820,954 |  |  | 1,799,920 |
Capital Surplus, Paid In | 8,710,844 |  |  | 8,460,876 |
Retained Earnings | 4,496,830 |  |  | 4,142,515 |
Accumulated Other Comprehensive Loss | (29,581) |  |  | (33,737) |
Treasury Stock | (180,334) |  |  | (195,682) |
Common Shareholders' Equity | 14,818,713 |  |  | 14,173,892 |
Commitments and Contingencies (Note 9) |  |  |
Total Liabilities and Capitalization | $ | 58,352,454 |  |  | $ | 55,612,245 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
1

EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)

| For the Three Months Ended June 30, |  | For the Six Months Ended June 30,
(Thousands of Dollars, Except Share Information) | 2024 |  | 2023 |  | 2024 |  | 2023
Operating Revenues | $ | 2,533,522 |  |  | $ | 2,629,342 |  |  | $ | 5,866,097 |  |  | $ | 6,424,985 |
Operating Expenses: |  |  |  |  |  |  |
Purchased Power, Purchased Natural Gas and Transmission | 841,431 |  |  | 1,161,067 |  |  | 2,077,387 |  |  | 3,064,313 |
Operations and Maintenance | 464,424 |  |  | 427,290 |  |  | 927,388 |  |  | 881,852 |
Depreciation | 354,591 |  |  | 319,995 |  |  | 694,505 |  |  | 632,949 |
Amortization | (114,137) |  |  | (218,422) |  |  | (116,462) |  |  | (294,481) |
Energy Efficiency Programs | 145,288 |  |  | 145,823 |  |  | 358,767 |  |  | 368,774 |
Taxes Other Than Income Taxes | 239,427 |  |  | 232,927 |  |  | 476,042 |  |  | 461,344 |
Total Operating Expenses | 1,931,024 |  |  | 2,068,680 |  |  | 4,417,627 |  |  | 5,114,751 |
Operating Income | 602,498 |  |  | 560,662 |  |  | 1,448,470 |  |  | 1,310,234 |
Interest Expense | 271,316 |  |  | 207,313 |  |  | 522,064 |  |  | 401,858 |
Impairment of Offshore Wind Investment | — |  |  | 401,000 |  |  | — |  |  | 401,000 |
Other Income, Net | 115,285 |  |  | 94,875 |  |  | 206,315 |  |  | 183,857 |
Income Before Income Tax Expense | 446,467 |  |  | 47,224 |  |  | 1,132,721 |  |  | 691,233 |
Income Tax Expense | 109,246 |  |  | 29,922 |  |  | 271,772 |  |  | 180,893 |
Net Income | 337,221 |  |  | 17,302 |  |  | 860,949 |  |  | 510,340 |
Net Income Attributable to Noncontrolling Interests | 1,880 |  |  | 1,880 |  |  | 3,759 |  |  | 3,759 |
Net Income Attributable to Common Shareholders | $ | 335,341 |  |  | $ | 15,422 |  |  | $ | 857,190 |  |  | $ | 506,581 |
Basic Earnings Per Common Share | $ | 0.95 |  |  | $ | 0.04 |  |  | $ | 2.44 |  |  | $ | 1.45 |
Diluted Earnings Per Common Share | $ | 0.95 |  |  | $ | 0.04 |  |  | $ | 2.43 |  |  | $ | 1.45 |
Weighted Average Common Shares Outstanding: |  |  |  |  |  |  |
Basic | 353,212,378 |  |  | 349,462,359 |  |  | 351,964,747 |  |  | 349,339,752 |
Diluted | 353,419,658 |  |  | 349,729,982 |  |  | 352,208,440 |  |  | 349,670,996 |

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) | 2024 |  | 2023 |  | 2024 |  | 2023
Net Income | $ | 337,221 |  |  | $ | 17,302 |  |  | $ | 860,949 |  |  | $ | 510,340 |
Other Comprehensive (Loss)/Income, Net of Tax: |  |  |  |  |  |  |
Qualified Cash Flow Hedging Instruments | 5 |  |  | 5 |  |  | 10 |  |  | 10 |
Changes in Unrealized Gains on Marketable Securities | — |  |  | — |  |  | — |  |  | 1,254 |
Changes in Funded Status of Pension, SERP and PBOP Benefit Plans | (1,052) |  |  | 4,083 |  |  | 4,146 |  |  | 6,054 |
Other Comprehensive (Loss)/Income, Net of Tax | (1,047) |  |  | 4,088 |  |  | 4,156 |  |  | 7,318 |
Comprehensive Income Attributable to Noncontrolling Interests | (1,880) |  |  | (1,880) |  |  | (3,759) |  |  | (3,759) |
Comprehensive Income Attributable to Common Shareholders | $ | 334,294 |  |  | $ | 19,510 |  |  | $ | 861,346 |  |  | $ | 513,899 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
2

EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY
(Unaudited)

| For the Six Months Ended June 30, 2024
| Common Shares | Capital Surplus, Paid In | Retained Earnings | Accumulated Other Comprehensive Loss | Treasury Stock | Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information) | Shares | Amount
Balance as of January 1, 2024 | 349,540,266 |  | $ | 1,799,920 |  | $ | 8,460,876 |  | $ | 4,142,515 |  | $ | (33,737) |  | $ | (195,682) |  | $ | 14,173,892 |
Net Income |  |  |  | 523,728 |  |  |  | 523,728 |
Dividends on Common Shares - $0.715 Per Share |  |  |  | (250,770) |  |  |  | (250,770) |
Dividends on Preferred Stock |  |  |  | (1,880) |  |  |  | (1,880) |
Issuance of Common Shares - $5 par value | 1,292,892 |  | 6,465 |  | 69,972 |  |  |  |  | 76,437 |
Long-Term Incentive Plan Activity |  |  | (22,405) |  |  |  |  | (22,405) |
Issuance of Treasury Shares | 546,256 |  |  | 30,190 |  |  |  | 10,235 |  | 40,425 |
Capital Stock Expense |  |  | (1,042) |  |  |  |  | (1,042) |
Other Comprehensive Income |  |  |  |  | 5,203 |  |  | 5,203 |
Balance as of March 31, 2024 | 351,379,414 |  | 1,806,385 |  | 8,537,591 |  | 4,413,593 |  | (28,534) |  | (185,447) |  | 14,543,588 |
Net Income |  |  |  | 337,221 |  |  |  | 337,221 |
Dividends on Common Shares - $0.715 Per Share |  |  |  | (252,104) |  |  |  | (252,104) |
Dividends on Preferred Stock |  |  |  | (1,880) |  |  |  | (1,880) |
Issuance of Common Shares - $5 par value | 2,913,757 |  | 14,569 |  | 160,088 |  |  |  |  | 174,657 |
Long-Term Incentive Plan Activity |  |  | 4,245 |  |  |  |  | 4,245 |
Issuance of Treasury Shares | 272,900 |  |  | 10,783 |  |  |  | 5,113 |  | 15,896 |
Capital Stock Expense |  |  | (1,863) |  |  |  |  | (1,863) |
Other Comprehensive Loss |  |  |  |  | (1,047) |  |  | (1,047) |
Balance as of June 30, 2024 | 354,566,071 |  | $ | 1,820,954 |  | $ | 8,710,844 |  | $ | 4,496,830 |  | $ | (29,581) |  | $ | (180,334) |  | $ | 14,818,713 |

| For the Six Months Ended June 30, 2023
| Common Shares | Capital Surplus, Paid In | Retained Earnings | Accumulated Other Comprehensive Loss | Treasury Stock | Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information) | Shares | Amount
Balance as of January 1, 2023 | 348,443,855 |  | $ | 1,799,920 |  | $ | 8,401,731 |  | $ | 5,527,153 |  | $ | (39,421) |  | $ | (216,225) |  | $ | 15,473,158 |
Net Income |  |  |  | 493,039 |  |  |  | 493,039 |
Dividends on Common Shares - $0.675 Per Share |  |  |  | (235,354) |  |  |  | (235,354) |
Dividends on Preferred Stock |  |  |  | (1,880) |  |  |  | (1,880) |
Long-Term Incentive Plan Activity |  |  | (13,141) |  |  |  |  | (13,141) |
Issuance of Treasury Shares | 364,227 |  |  | 23,495 |  |  |  | 6,824 |  | 30,319 |
Other Comprehensive Income |  |  |  |  | 3,230 |  |  | 3,230 |
Balance as of March 31, 2023 | 348,808,082 |  | 1,799,920 |  | 8,412,085 |  | 5,782,958 |  | (36,191) |  | (209,401) |  | 15,749,371 |
Net Income |  |  |  | 17,302 |  |  |  | 17,302 |
Dividends on Common Shares - $0.675 Per Share |  |  |  | (235,491) |  |  |  | (235,491) |
Dividends on Preferred Stock |  |  |  | (1,880) |  |  |  | (1,880) |
Long-Term Incentive Plan Activity |  |  | 5,155 |  |  |  |  | 5,155 |
Issuance of Treasury Shares | 213,854 |  |  | 11,546 |  |  |  | 4,007 |  | 15,553 |
Other Comprehensive Income |  |  |  |  | 4,088 |  |  | 4,088 |
Balance as of June 30, 2023 | 349,021,936 |  | $ | 1,799,920 |  | $ | 8,428,786 |  | $ | 5,562,889 |  | $ | (32,103) |  | $ | (205,394) |  | $ | 15,554,098 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
3

EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

| For the Six Months Ended June 30,
(Thousands of Dollars) | 2024 |  | 2023
Operating Activities: |  |  |
Net Income | $ | 860,949 |  |  | $ | 510,340 |
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: |  |  |
Depreciation | 694,505 |  |  | 632,949 |
Deferred Income Taxes | 297,901 |  |  | 155,035 |
Uncollectible Expense | 26,279 |  |  | 24,171 |
Pension, SERP and PBOP Income, Net | (35,719) |  |  | (46,600) |
Pension Contributions | (2,500) |  |  | (2,400) |
Regulatory Under Recoveries, Net | (383,152) |  |  | (112,050) |
Amortization | (116,462) |  |  | (294,481) |
Cost of Removal Expenditures | (113,024) |  |  | (183,552) |
Impairment of Offshore Wind Investment | — |  |  | 401,000 |
Other | (99,544) |  |  | (13,423) |
Changes in Current Assets and Liabilities: |  |  |
Receivables and Unbilled Revenues, Net | (95,839) |  |  | 137,819 |
Taxes Receivable/Accrued, Net | 41,275 |  |  | 49,201 |
Accounts Payable | (82,355) |  |  | (489,132) |
Other Current Assets and Liabilities, Net | (30,288) |  |  | (121,600) |
Net Cash Flows Provided by Operating Activities | 962,026 |  |  | 647,277 |
Investing Activities: |  |  |
Investments in Property, Plant and Equipment | (2,220,917) |  |  | (2,039,512) |
Proceeds from Sales of Marketable Securities | 91,437 |  |  | 215,570 |
Purchases of Marketable Securities | (83,502) |  |  | (194,786) |
Investments in Unconsolidated Affiliates | (729,354) |  |  | (390,002) |
Other Investing Activities | 11,355 |  |  | 11,055 |
Net Cash Flows Used in Investing Activities | (2,930,981) |  |  | (2,397,675) |
Financing Activities: |  |  |
Issuance of Common Shares, Net of Issuance Costs | 248,189 |  |  | — |
Cash Dividends on Common Shares | (490,910) |  |  | (458,959) |
Cash Dividends on Preferred Stock | (3,759) |  |  | (3,759) |
Decrease in Notes Payable | (698,252) |  |  | (589,200) |
Repayment of Rate Reduction Bonds | (21,605) |  |  | (21,605) |
Issuance of Long-Term Debt | 3,850,000 |  |  | 3,361,000 |
Retirement of Long-Term Debt | (900,000) |  |  | (853,000) |
Other Financing Activities | (48,493) |  |  | (27,839) |
Net Cash Flows Provided by Financing Activities | 1,935,170 |  |  | 1,406,638 |
Net Decrease in Cash and Restricted Cash | (33,785) |  |  | (343,760) |
Cash and Restricted Cash - Beginning of Period | 166,418 |  |  | 521,752 |
Cash and Restricted Cash - End of Period | $ | 132,633 |  |  | $ | 177,992 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
4

THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED BALANCE SHEETS
(Unaudited)

(Thousands of Dollars) | As of June 30, 2024 |  | As of December 31, 2023
ASSETS |  |  |
Current Assets: |  |  |
Cash | $ | — |  |  | $ | 10,213 |
Receivables, Net (net of allowance for uncollectible accounts of $308,586 and $296,030 as of June 30, 2024 and December 31, 2023, respectively) | 586,542 |  |  | 558,993 |
Accounts Receivable from Affiliated Companies | 43,052 |  |  | 60,450 |
Unbilled Revenues | 58,505 |  |  | 57,403 |
Materials, Supplies and REC Inventory | 192,600 |  |  | 156,467 |
Regulatory Assets | 860,776 |  |  | 480,369 |
Prepayments and Other Current Assets | 56,444 |  |  | 94,789 |
Total Current Assets | 1,797,919 |  |  | 1,418,684 |
Property, Plant and Equipment, Net | 12,688,615 |  |  | 12,340,192 |
Deferred Debits and Other Assets: |  |  |
Regulatory Assets | 1,731,870 |  |  | 1,662,778 |
Prepaid Pension and PBOP | 136,231 |  |  | 129,801 |
Other Long-Term Assets | 329,433 |  |  | 298,169 |
Total Deferred Debits and Other Assets | 2,197,534 |  |  | 2,090,748 |
Total Assets | $ | 16,684,068 |  |  | $ | 15,849,624 |
LIABILITIES AND CAPITALIZATION |  |  |
Current Liabilities: |  |  |
Notes Payable to Eversource Parent | $ | 407,800 |  |  | $ | 249,670 |
Long-Term Debt – Current Portion | 139,845 |  |  | — |
Accounts Payable | 586,253 |  |  | 622,055 |
Accounts Payable to Affiliated Companies | 96,302 |  |  | 134,726 |
Obligations to Third Party Suppliers | 67,364 |  |  | 75,753 |
Regulatory Liabilities | 133,305 |  |  | 102,239 |
Derivative Liabilities | 77,391 |  |  | 81,944 |
Other Current Liabilities | 166,144 |  |  | 127,703 |
Total Current Liabilities | 1,674,404 |  |  | 1,394,090 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated Deferred Income Taxes | 2,024,055 |  |  | 1,860,122 |
Regulatory Liabilities | 1,351,877 |  |  | 1,315,928 |
Other Long-Term Liabilities | 227,921 |  |  | 258,185 |
Total Deferred Credits and Other Liabilities | 3,603,853 |  |  | 3,434,235 |
Long-Term Debt | 4,814,280 |  |  | 4,814,429 |
Preferred Stock Not Subject to Mandatory Redemption | 116,200 |  |  | 116,200 |
Common Stockholder's Equity: |  |  |
Common Stock | 60,352 |  |  | 60,352 |
Capital Surplus, Paid In | 3,584,265 |  |  | 3,384,265 |
Retained Earnings | 2,830,542 |  |  | 2,645,868 |
Accumulated Other Comprehensive Income | 172 |  |  | 185 |
Common Stockholder's Equity | 6,475,331 |  |  | 6,090,670 |
Commitments and Contingencies (Note 9) |  |  |
Total Liabilities and Capitalization | $ | 16,684,068 |  |  | $ | 15,849,624 |

The accompanying notes are an integral part of these unaudited condensed financial statements.
5

THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF INCOME
(Unaudited)

| For the Three Months Ended June 30, |  | For the Six Months Ended June 30,
(Thousands of Dollars) | 2024 |  | 2023 |  | 2024 |  | 2023
Operating Revenues | $ | 964,623 |  |  | $ | 1,034,148 |  |  | $ | 2,085,914 |  |  | $ | 2,373,054 |
Operating Expenses: |  |  |  |  |  |  |
Purchased Power and Transmission | 480,426 |  |  | 626,411 |  |  | 1,046,423 |  |  | 1,476,976 |
Operations and Maintenance | 197,445 |  |  | 166,566 |  |  | 384,209 |  |  | 326,882 |
Depreciation | 100,411 |  |  | 93,652 |  |  | 198,856 |  |  | 185,889 |
Amortization of Regulatory Liabilities, Net | (155,031) |  |  | (189,922) |  |  | (246,744) |  |  | (312,236) |
Energy Efficiency Programs | 31,540 |  |  | 28,137 |  |  | 67,140 |  |  | 60,783 |
Taxes Other Than Income Taxes | 96,393 |  |  | 94,602 |  |  | 200,193 |  |  | 196,184 |
Total Operating Expenses | 751,184 |  |  | 819,446 |  |  | 1,650,077 |  |  | 1,934,478 |
Operating Income | 213,439 |  |  | 214,702 |  |  | 435,837 |  |  | 438,576 |
Interest Expense | 61,894 |  |  | 47,771 |  |  | 116,718 |  |  | 92,972 |
Other Income, Net | 22,977 |  |  | 13,362 |  |  | 39,445 |  |  | 28,299 |
Income Before Income Tax Expense | 174,522 |  |  | 180,293 |  |  | 358,564 |  |  | 373,903 |
Income Tax Expense | 42,921 |  |  | 46,993 |  |  | 88,610 |  |  | 92,187 |
Net Income | $ | 131,601 |  |  | $ | 133,300 |  |  | $ | 269,954 |  |  | $ | 281,716 |

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,
(Thousands of Dollars) | 2024 |  | 2023 |  | 2024 |  | 2023
Net Income | $ | 131,601 |  |  | $ | 133,300 |  |  | $ | 269,954 |  |  | $ | 281,716 |
Other Comprehensive (Loss)/Income, Net of Tax: |  |  |  |  |  |  |
Qualified Cash Flow Hedging Instruments | (6) |  |  | (7) |  |  | (13) |  |  | (14) |
Changes in Unrealized Gains on Marketable Securities | — |  |  | — |  |  | — |  |  | 43 |
Other Comprehensive (Loss)/Income, Net of Tax | (6) |  |  | (7) |  |  | (13) |  |  | 29 |
Comprehensive Income | $ | 131,595 |  |  | $ | 133,293 |  |  | $ | 269,941 |  |  | $ | 281,745 |

The accompanying notes are an integral part of these unaudited condensed financial statements.
6

THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY
(Unaudited)

| For the Six Months Ended June 30, 2024
| Common Stock |  | Capital Surplus, Paid In |  | Retained Earnings |  | Accumulated Other Comprehensive Income |  | Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information) | Stock |  | Amount |  |  |  |
Balance as of January 1, 2024 | 6,035,205 |  |  | $ | 60,352 |  |  | $ | 3,384,265 |  |  | $ | 2,645,868 |  |  | $ | 185 |  |  | $ | 6,090,670 |
Net Income |  |  |  |  |  |  | 138,353 |  |  |  |  | 138,353 |
Dividends on Preferred Stock |  |  |  |  |  |  | (1,390) |  |  |  |  | (1,390) |
Dividends on Common Stock |  |  |  |  |  |  | (82,500) |  |  |  |  | (82,500) |
Capital Contributions from Eversource Parent |  |  |  |  | 100,000 |  |  |  |  |  |  | 100,000 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (7) |  |  | (7) |
Balance as of March 31, 2024 | 6,035,205 |  |  | 60,352 |  |  | 3,484,265 |  |  | 2,700,331 |  |  | 178 |  |  | 6,245,126 |
Net Income |  |  |  |  |  |  | 131,601 |  |  |  |  | 131,601 |
Dividends on Preferred Stock |  |  |  |  |  |  | (1,390) |  |  |  |  | (1,390) |
Capital Contributions from Eversource Parent |  |  |  |  | 100,000 |  |  |  |  |  |  | 100,000 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (6) |  |  | (6) |
Balance as of June 30, 2024 | 6,035,205 |  |  | $ | 60,352 |  |  | $ | 3,584,265 |  |  | $ | 2,830,542 |  |  | $ | 172 |  |  | $ | 6,475,331 |

| For the Six Months Ended June 30, 2023
| Common Stock |  | Capital Surplus, Paid In |  | Retained Earnings |  | Accumulated Other Comprehensive Income |  | Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information) | Stock |  | Amount |  |  |  |
Balance as of January 1, 2023 | 6,035,205 |  |  | $ | 60,352 |  |  | $ | 3,260,765 |  |  | $ | 2,463,094 |  |  | $ | 169 |  |  | $ | 5,784,380 |
Net Income |  |  |  |  |  |  | 148,416 |  |  |  |  | 148,416 |
Dividends on Preferred Stock |  |  |  |  |  |  | (1,390) |  |  |  |  | (1,390) |
Dividends on Common Stock |  |  |  |  |  |  | (82,600) |  |  |  |  | (82,600) |
Other Comprehensive Income |  |  |  |  |  |  |  |  | 36 |  |  | 36 |
Balance as of March 31, 2023 | 6,035,205 |  |  | 60,352 |  |  | 3,260,765 |  |  | 2,527,520 |  |  | 205 |  |  | 5,848,842 |
Net Income |  |  |  |  |  |  | 133,300 |  |  |  |  | 133,300 |
Dividends on Preferred Stock |  |  |  |  |  |  | (1,390) |  |  |  |  | (1,390) |
Dividends on Common Stock |  |  |  |  |  |  | (82,600) |  |  |  |  | (82,600) |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (7) |  |  | (7) |
Balance as of June 30, 2023 | 6,035,205 |  |  | $ | 60,352 |  |  | $ | 3,260,765 |  |  | $ | 2,576,830 |  |  | $ | 198 |  |  | $ | 5,898,145 |

The accompanying notes are an integral part of these unaudited condensed financial statements.
7

THE CONNECTICUT LIGHT AND POWER COMPANY
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)

| For the Six Months Ended June 30,
(Thousands of Dollars) | 2024 |  | 2023
Operating Activities: |  |  |
Net Income | $ | 269,954 |  |  | $ | 281,716 |
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: |  |  |
Depreciation | 198,856 |  |  | 185,889 |
Deferred Income Taxes | 146,839 |  |  | 105,162 |
Uncollectible Expense | 6,326 |  |  | 4,750 |
Pension, SERP, and PBOP Income, Net | (6,379) |  |  | (9,083) |
Regulatory (Under)/Over Recoveries, Net | (117,569) |  |  | 39,524 |
Amortization of Regulatory Liabilities, Net | (246,744) |  |  | (312,236) |
Cost of Removal Expenditures | (32,317) |  |  | (36,781) |
Other | (42,305) |  |  | (34,571) |
Changes in Current Assets and Liabilities: |  |  |
Receivables and Unbilled Revenues, Net | (53,861) |  |  | 20,542 |
Taxes Receivable/Accrued, Net | 83,731 |  |  | 132,751 |
Accounts Payable | (54,887) |  |  | (251,326) |
Other Current Assets and Liabilities, Net | (41,887) |  |  | 2,711 |
Net Cash Flows Provided by Operating Activities | 109,757 |  |  | 129,048 |
Investing Activities: |  |  |
Investments in Property, Plant and Equipment | (532,235) |  |  | (499,920) |
Other Investing Activities | — |  |  | 173 |
Net Cash Flows Used in Investing Activities | (532,235) |  |  | (499,747) |
Financing Activities: |  |  |
Cash Dividends on Common Stock | (82,500) |  |  | (165,200) |
Cash Dividends on Preferred Stock | (2,779) |  |  | (2,779) |
Capital Contributions from Eversource Parent | 200,000 |  |  | — |
Issuance of Long-Term Debt | 350,000 |  |  | 500,000 |
Retirement of Long-Term Debt | — |  |  | (400,000) |
(Decrease)/Increase in Notes Payable to Eversource Parent | (49,200) |  |  | 449,000 |
Other Financing Activities | (4,218) |  |  | (6,521) |
Net Cash Flows Provided by Financing Activities | 411,303 |  |  | 374,500 |
Net (Decrease)/Increase in Cash and Restricted Cash | (11,175) |  |  | 3,801 |
Cash and Restricted Cash - Beginning of Period | 12,243 |  |  | 20,327 |
Cash and Restricted Cash - End of Period | $ | 1,068 |  |  | $ | 24,128 |

The accompanying notes are an integral part of these unaudited condensed financial statements.
8

NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)

(Thousands of Dollars) | As of June 30, 2024 |  | As of December 31, 2023
ASSETS |  |  |
Current Assets: |  |  |
Cash | $ | 2,730 |  |  | $ | 6,740 |
Receivables, Net (net of allowance for uncollectible accounts of $106,174 and $97,026 as of June 30, 2024 and December 31, 2023, respectively) | 490,160 |  |  | 487,707 |
Accounts Receivable from Affiliated Companies | 103,877 |  |  | 74,634 |
Unbilled Revenues | 62,319 |  |  | 49,897 |
Materials, Supplies and REC Inventory | 166,717 |  |  | 173,770 |
Regulatory Assets | 757,447 |  |  | 676,083 |
Prepayments and Other Current Assets | 37,050 |  |  | 41,464 |
Total Current Assets | 1,620,300 |  |  | 1,510,295 |
Property, Plant and Equipment, Net | 13,322,862 |  |  | 12,753,787 |
Deferred Debits and Other Assets: |  |  |
Regulatory Assets | 1,305,490 |  |  | 1,281,836 |
Prepaid Pension and PBOP | 654,183 |  |  | 608,617 |
Other Long-Term Assets | 130,839 |  |  | 116,978 |
Total Deferred Debits and Other Assets | 2,090,512 |  |  | 2,007,431 |
Total Assets | $ | 17,033,674 |  |  | $ | 16,271,513 |
LIABILITIES AND CAPITALIZATION |  |  |
Current Liabilities: |  |  |
Notes Payable | $ | 236,500 |  |  | $ | 365,847 |
Accounts Payable | 483,571 |  |  | 599,696 |
Accounts Payable to Affiliated Companies | 132,079 |  |  | 144,622 |
Obligations to Third Party Suppliers | 232,608 |  |  | 139,823 |
Renewable Portfolio Standards Compliance Obligations | 70,689 |  |  | 116,010 |
Regulatory Liabilities | 413,492 |  |  | 368,070 |
Other Current Liabilities | 75,516 |  |  | 84,688 |
Total Current Liabilities | 1,644,455 |  |  | 1,818,756 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated Deferred Income Taxes | 1,925,079 |  |  | 1,849,613 |
Regulatory Liabilities | 1,619,614 |  |  | 1,585,311 |
Other Long-Term Liabilities | 335,403 |  |  | 327,388 |
Total Deferred Credits and Other Liabilities | 3,880,096 |  |  | 3,762,312 |
Long-Term Debt | 5,092,959 |  |  | 4,496,947 |
Preferred Stock Not Subject to Mandatory Redemption | 43,000 |  |  | 43,000 |
Common Stockholder's Equity: |  |  |
Common Stock | — |  |  | — |
Capital Surplus, Paid In | 3,313,842 |  |  | 3,013,842 |
Retained Earnings | 3,059,312 |  |  | 3,136,612 |
Accumulated Other Comprehensive Income | 10 |  |  | 44 |
Common Stockholder's Equity | 6,373,164 |  |  | 6,150,498 |
Commitments and Contingencies (Note 9) |  |  |
Total Liabilities and Capitalization | $ | 17,033,674 |  |  | $ | 16,271,513 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
9

NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)

| For the Three Months Ended June 30, |  | For the Six Months Ended June 30,
(Thousands of Dollars) | 2024 |  | 2023 |  | 2024 |  | 2023
Operating Revenues | $ | 845,068 |  |  | $ | 818,968 |  |  | $ | 1,792,683 |  |  | $ | 1,775,251 |
Operating Expenses: |  |  |  |  |  |  |
Purchased Power and Transmission | 209,348 |  |  | 266,560 |  |  | 482,653 |  |  | 627,485 |
Operations and Maintenance | 163,580 |  |  | 146,852 |  |  | 337,252 |  |  | 312,935 |
Depreciation | 100,286 |  |  | 92,863 |  |  | 197,208 |  |  | 183,292 |
Amortization of Regulatory Assets/(Liabilities), Net | 21,236 |  |  | (1,400) |  |  | 69,627 |  |  | 21,385 |
Energy Efficiency Programs | 66,662 |  |  | 70,687 |  |  | 148,962 |  |  | 156,904 |
Taxes Other Than Income Taxes | 71,049 |  |  | 66,232 |  |  | 131,061 |  |  | 119,743 |
Total Operating Expenses | 632,161 |  |  | 641,794 |  |  | 1,366,763 |  |  | 1,421,744 |
Operating Income | 212,907 |  |  | 177,174 |  |  | 425,920 |  |  | 353,507 |
Interest Expense | 54,689 |  |  | 46,761 |  |  | 104,113 |  |  | 91,626 |
Other Income, Net | 48,421 |  |  | 40,909 |  |  | 95,536 |  |  | 80,782 |
Income Before Income Tax Expense | 206,639 |  |  | 171,322 |  |  | 417,343 |  |  | 342,663 |
Income Tax Expense | 49,036 |  |  | 36,579 |  |  | 99,763 |  |  | 74,107 |
Net Income | $ | 157,603 |  |  | $ | 134,743 |  |  | $ | 317,580 |  |  | $ | 268,556 |

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) | 2024 |  | 2023 |  | 2024 |  | 2023
Net Income | $ | 157,603 |  |  | $ | 134,743 |  |  | $ | 317,580 |  |  | $ | 268,556 |
Other Comprehensive Loss, Net of Tax: |  |  |  |  |  |  |
Changes in Funded Status of SERP Benefit Plan | (23) |  |  | (32) |  |  | (44) |  |  | (65) |
Qualified Cash Flow Hedging Instruments | 5 |  |  | 5 |  |  | 10 |  |  | 10 |
Changes in Unrealized Gains on Marketable Securities | — |  |  | — |  |  | — |  |  | 12 |
Other Comprehensive Loss, Net of Tax | (18) |  |  | (27) |  |  | (34) |  |  | (43) |
Comprehensive Income | $ | 157,585 |  |  | $ | 134,716 |  |  | $ | 317,546 |  |  | $ | 268,513 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
10

NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY
(Unaudited)

| For the Six Months Ended June 30, 2024
| Common Stock |  | Capital Surplus, Paid In |  | Retained Earnings |  | Accumulated Other Comprehensive Income |  | Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information) | Stock |  | Amount |  |  |  |
Balance as of January 1, 2024 | 200 |  |  | $ | — |  |  | $ | 3,013,842 |  |  | $ | 3,136,612 |  |  | $ | 44 |  |  | $ | 6,150,498 |
Net Income |  |  |  |  |  |  | 159,977 |  |  |  |  | 159,977 |
Dividends on Preferred Stock |  |  |  |  |  |  | (490) |  |  |  |  | (490) |
Dividends on Common Stock |  |  |  |  |  |  | (96,700) |  |  |  |  | (96,700) |
Capital Contributions from Eversource Parent |  |  |  |  | 300,000 |  |  |  |  |  |  | 300,000 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (16) |  |  | (16) |
Balance as of March 31, 2024 | 200 |  |  | — |  |  | 3,313,842 |  |  | 3,199,399 |  |  | 28 |  |  | 6,513,269 |
Net Income |  |  |  |  |  |  | 157,603 |  |  |  |  | 157,603 |
Dividends on Preferred Stock |  |  |  |  |  |  | (490) |  |  |  |  | (490) |
Dividends on Common Stock |  |  |  |  |  |  | (297,200) |  |  |  |  | (297,200) |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (18) |  |  | (18) |
Balance as of June 30, 2024 | 200 |  |  | $ | — |  |  | $ | 3,313,842 |  |  | $ | 3,059,312 |  |  | $ | 10 |  |  | $ | 6,373,164 |

| For the Six Months Ended June 30, 2023
| Common Stock |  | Capital Surplus, Paid In |  | Retained Earnings |  | Accumulated Other Comprehensive Income |  | Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information) | Stock |  | Amount |  |  |  |
Balance as of January 1, 2023 | 200 |  |  | $ | — |  |  | $ | 2,778,942 |  |  | $ | 2,921,444 |  |  | $ | 284 |  |  | $ | 5,700,670 |
Net Income |  |  |  |  |  |  | 133,813 |  |  |  |  | 133,813 |
Dividends on Preferred Stock |  |  |  |  |  |  | (490) |  |  |  |  | (490) |
Dividends on Common Stock |  |  |  |  |  |  | (327,400) |  |  |  |  | (327,400) |
Capital Contributions from Eversource Parent |  |  |  |  | 31,300 |  |  |  |  |  |  | 31,300 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (16) |  |  | (16) |
Balance as of March 31, 2023 | 200 |  |  | — |  |  | 2,810,242 |  |  | 2,727,367 |  |  | 268 |  |  | 5,537,877 |
Net Income |  |  |  |  |  |  | 134,743 |  |  |  |  | 134,743 |
Dividends on Preferred Stock |  |  |  |  |  |  | (490) |  |  |  |  | (490) |
Capital Contributions from Eversource Parent |  |  |  |  | 81,000 |  |  |  |  |  |  | 81,000 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (27) |  |  | (27) |
Balance as of June 30, 2023 | 200 |  |  | $ | — |  |  | $ | 2,891,242 |  |  | $ | 2,861,620 |  |  | $ | 241 |  |  | $ | 5,753,103 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
11

NSTAR ELECTRIC COMPANY AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

| For the Six Months Ended June 30,
(Thousands of Dollars) | 2024 |  | 2023
Operating Activities: |  |  |
Net Income | $ | 317,580 |  |  | $ | 268,556 |
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: |  |  |
Depreciation | 197,208 |  |  | 183,292 |
Deferred Income Taxes | 54,640 |  |  | 66,926 |
Uncollectible Expense | 12,007 |  |  | 7,759 |
Pension, SERP and PBOP Income, Net | (18,003) |  |  | (20,460) |
Regulatory Under Recoveries, Net | (157,521) |  |  | (126,487) |
Amortization of Regulatory Assets, Net | 69,627 |  |  | 21,385 |
Cost of Removal Expenditures | (22,832) |  |  | (33,750) |
Other | (27,840) |  |  | (12,211) |
Changes in Current Assets and Liabilities: |  |  |
Receivables and Unbilled Revenues, Net | (41,197) |  |  | (9,745) |
Taxes Receivable/Accrued, Net | (5,328) |  |  | 28,662 |
Accounts Payable | (77,371) |  |  | (68,720) |
Other Current Assets and Liabilities, Net | 40,403 |  |  | (71,745) |
Net Cash Flows Provided by Operating Activities | 341,373 |  |  | 233,462 |
Investing Activities: |  |  |
Investments in Property, Plant and Equipment | (729,758) |  |  | (677,596) |
Other Investing Activities | — |  |  | 48 |
Net Cash Flows Used in Investing Activities | (729,758) |  |  | (677,548) |
Financing Activities: |  |  |
Cash Dividends on Common Stock | (393,900) |  |  | (327,400) |
Cash Dividends on Preferred Stock | (980) |  |  | (980) |
Issuance of Long-Term Debt | 600,000 |  |  | — |
Capital Contributions from Eversource Parent | 300,000 |  |  | 112,300 |
(Decrease)/Increase in Notes Payable | (129,347) |  |  | 324,000 |
Other Financing Activities | (6,081) |  |  | 8 |
Net Cash Flows Provided by Financing Activities | 369,692 |  |  | 107,928 |
Net Decrease in Cash and Restricted Cash | (18,693) |  |  | (336,158) |
Cash and Restricted Cash - Beginning of Period | 22,785 |  |  | 345,293 |
Cash and Restricted Cash - End of Period | $ | 4,092 |  |  | $ | 9,135 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
12

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)

(Thousands of Dollars) | As of June 30, 2024 |  | As of December 31, 2023
ASSETS |  |  |
Current Assets: |  |  |
Cash | $ | 252 |  |  | $ | 240 |
Receivables, Net (net of allowance for uncollectible accounts of $14,135 and $14,322 as of June 30, 2024 and December 31, 2023, respectively) | 155,242 |  |  | 152,276 |
Accounts Receivable from Affiliated Companies | 15,226 |  |  | 18,214 |
Unbilled Revenues | 49,398 |  |  | 55,012 |
Taxes Receivable | 38,220 |  |  | 27,146 |
Materials, Supplies and REC Inventory | 81,032 |  |  | 77,066 |
Regulatory Assets | 175,003 |  |  | 189,450 |
Special Deposits | 30,651 |  |  | 31,586 |
Prepayments | 23,456 |  |  | 18,489 |
Total Current Assets | 568,480 |  |  | 569,479 |
Property, Plant and Equipment, Net | 4,833,400 |  |  | 4,574,652 |
Deferred Debits and Other Assets: |  |  |
Regulatory Assets | 922,613 |  |  | 773,783 |
Prepaid Pension and PBOP | 64,530 |  |  | 58,979 |
Other Long-Term Assets | 19,383 |  |  | 16,558 |
Total Deferred Debits and Other Assets | 1,006,526 |  |  | 849,320 |
Total Assets | $ | 6,408,406 |  |  | $ | 5,993,451 |
LIABILITIES AND CAPITALIZATION |  |  |
Current Liabilities: |  |  |
Notes Payable to Eversource Parent | $ | 132,000 |  |  | $ | 233,000 |
Rate Reduction Bonds – Current Portion | 43,210 |  |  | 43,210 |
Accounts Payable | 288,517 |  |  | 205,744 |
Accounts Payable to Affiliated Companies | 33,835 |  |  | 41,272 |
Regulatory Liabilities | 79,112 |  |  | 117,515 |
Other Current Liabilities | 73,148 |  |  | 72,328 |
Total Current Liabilities | 649,822 |  |  | 713,069 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated Deferred Income Taxes | 758,015 |  |  | 691,532 |
Regulatory Liabilities | 392,184 |  |  | 393,574 |
Other Long-Term Liabilities | 39,528 |  |  | 42,484 |
Total Deferred Credits and Other Liabilities | 1,189,727 |  |  | 1,127,590 |
Long-Term Debt | 1,731,461 |  |  | 1,431,591 |
Rate Reduction Bonds | 345,677 |  |  | 367,282 |
Common Stockholder's Equity: |  |  |
Common Stock | — |  |  | — |
Capital Surplus, Paid In | 1,798,134 |  |  | 1,698,134 |
Retained Earnings | 693,585 |  |  | 655,785 |
Common Stockholder's Equity | 2,491,719 |  |  | 2,353,919 |
Commitments and Contingencies (Note 9) |  |  |
Total Liabilities and Capitalization | $ | 6,408,406 |  |  | $ | 5,993,451 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
13

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)

| For the Three Months Ended June 30, |  | For the Six Months Ended June 30,
(Thousands of Dollars) | 2024 |  | 2023 |  | 2024 |  | 2023
Operating Revenues | $ | 287,311 |  |  | $ | 350,070 |  |  | $ | 613,427 |  |  | $ | 770,225 |
Operating Expenses: |  |  |  |  |  |  |
Purchased Power and Transmission | 36,995 |  |  | 144,829 |  |  | 124,933 |  |  | 371,514 |
Operations and Maintenance | 69,643 |  |  | 64,503 |  |  | 138,355 |  |  | 132,298 |
Depreciation | 38,127 |  |  | 34,702 |  |  | 75,536 |  |  | 68,790 |
Amortization of Regulatory Assets/(Liabilities), Net | 28,729 |  |  | (19,954) |  |  | 49,993 |  |  | (25,271) |
Energy Efficiency Programs | 9,695 |  |  | 9,149 |  |  | 20,871 |  |  | 19,376 |
Taxes Other Than Income Taxes | 24,465 |  |  | 25,531 |  |  | 47,780 |  |  | 47,636 |
Total Operating Expenses | 207,654 |  |  | 258,760 |  |  | 457,468 |  |  | 614,343 |
Operating Income | 79,657 |  |  | 91,310 |  |  | 155,959 |  |  | 155,882 |
Interest Expense | 20,259 |  |  | 19,106 |  |  | 39,453 |  |  | 36,649 |
Other Income, Net | 7,772 |  |  | 6,301 |  |  | 14,822 |  |  | 12,019 |
Income Before Income Tax Expense | 67,170 |  |  | 78,505 |  |  | 131,328 |  |  | 131,252 |
Income Tax Expense | 15,726 |  |  | 18,143 |  |  | 31,528 |  |  | 30,594 |
Net Income | $ | 51,444 |  |  | $ | 60,362 |  |  | $ | 99,800 |  |  | $ | 100,658 |

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) | 2024 |  | 2023 |  | 2024 |  | 2023
Net Income | $ | 51,444 |  |  | $ | 60,362 |  |  | $ | 99,800 |  |  | $ | 100,658 |
Other Comprehensive Income, Net of Tax: |  |  |  |  |  |  |
Changes in Unrealized Gains on Marketable Securities | — |  |  | — |  |  | — |  |  | 73 |
Other Comprehensive Income, Net of Tax | — |  |  | — |  |  | — |  |  | 73 |
Comprehensive Income | $ | 51,444 |  |  | $ | 60,362 |  |  | $ | 99,800 |  |  | $ | 100,731 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
14

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY
(Unaudited)

| For the Six Months Ended June 30, 2024
| 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, 2024 | 301 |  |  | $ | — |  |  | $ | 1,698,134 |  |  | $ | 655,785 |  |  | $ | — |  |  | $ | 2,353,919 |
Net Income |  |  |  |  |  |  | 48,356 |  |  |  |  | 48,356 |
Capital Contributions from Eversource Parent |  |  |  |  | 100,000 |  |  |  |  |  |  | 100,000 |
Balance as of March 31, 2024 | 301 |  |  | — |  |  | 1,798,134 |  |  | 704,141 |  |  | — |  |  | 2,502,275 |
Net Income |  |  |  |  |  |  | 51,444 |  |  |  |  | 51,444 |
Dividends on Common Stock |  |  |  |  |  |  | (62,000) |  |  |  |  | (62,000) |
Balance as of June 30, 2024 | 301 |  |  | $ | — |  |  | $ | 1,798,134 |  |  | $ | 693,585 |  |  | $ | — |  |  | $ | 2,491,719 |

| For the Six Months Ended June 30, 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 |
Net Income |  |  |  |  |  |  | 60,362 |  |  |  |  | 60,362 |
Dividends on Common Stock |  |  |  |  |  |  | (28,000) |  |  |  |  | (28,000) |
Capital Contributions from Eversource Parent |  |  |  |  | 100,000 |  |  |  |  |  |  | 100,000 |
Balance as of June 30, 2023 | 301 |  |  | $ | — |  |  | $ | 1,398,134 |  |  | $ | 616,784 |  |  | $ | — |  |  | $ | 2,014,918 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
15

PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

| For the Six Months Ended June 30,
(Thousands of Dollars) | 2024 |  | 2023
Operating Activities: |  |  |
Net Income | $ | 99,800 |  |  | $ | 100,658 |
Adjustments to Reconcile Net Income to Net Cash Flows Provided by/(Used In) Operating Activities: |  |  |
Depreciation | 75,536 |  |  | 68,790 |
Deferred Income Taxes | 64,545 |  |  | 89,761 |
Uncollectible Expense | 2,178 |  |  | (451) |
Pension, SERP and PBOP Income, Net | (4,469) |  |  | (5,197) |
Regulatory Under Recoveries, Net | (167,077) |  |  | (244,668) |
Amortization of Regulatory Assets/(Liabilities), Net | 49,993 |  |  | (25,271) |
Cost of Removal Expenditures | (20,358) |  |  | (15,678) |
Other | (2,691) |  |  | 3,896 |
Changes in Current Assets and Liabilities: |  |  |
Receivables and Unbilled Revenues, Net | 1,916 |  |  | 12,223 |
Taxes Receivable/Accrued, Net | (11,045) |  |  | 4,357 |
Accounts Payable | (3,697) |  |  | (45,255) |
Other Current Assets and Liabilities, Net | (8,142) |  |  | (35,773) |
Net Cash Flows Provided by/(Used In) Operating Activities | 76,489 |  |  | (92,608) |
Investing Activities: |  |  |
Investments in Property, Plant and Equipment | (289,667) |  |  | (276,676) |
Other Investing Activities | — |  |  | 296 |
Net Cash Flows Used in Investing Activities | (289,667) |  |  | (276,380) |
Financing Activities: |  |  |
Cash Dividends on Common Stock | (62,000) |  |  | (56,000) |
Capital Contributions from Eversource Parent | 100,000 |  |  | 100,000 |
Issuance of Long-Term Debt | 300,000 |  |  | 300,000 |
Repayment of Rate Reduction Bonds | (21,605) |  |  | (21,605) |
(Decrease)/Increase in Notes Payable to Eversource Parent | (101,000) |  |  | 53,000 |
Other Financing Activities | (3,140) |  |  | (5,460) |
Net Cash Flows Provided by Financing Activities | 212,255 |  |  | 369,935 |
Net (Decrease)/Increase in Cash and Restricted Cash | (923) |  |  | 947 |
Cash and Restricted Cash - Beginning of Period | 35,004 |  |  | 36,812 |
Cash and Restricted Cash - End of Period | $ | 34,081 |  |  | $ | 37,759 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
16

EVERSOURCE ENERGY AND SUBSIDIARIES
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
COMBINED NOTES TO CONDENSED FINANCIAL STATEMENTS (Unaudited)
Refer to the Glossary of Terms included in this combined Quarterly Report on Form 10-Q for abbreviations and acronyms used throughout the combined notes to the unaudited condensed financial statements.
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
A. Basis of Presentation
Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business. Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), Yankee Gas, NSTAR Gas and EGMA (natural gas utilities), and Aquarion (water utilities). Eversource provides energy delivery and/or water service to approximately 4.4 million electric, natural gas and water customers through twelve regulated utilities in Connecticut, Massachusetts and New Hampshire.
The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries. Intercompany transactions have been eliminated in consolidation. The accompanying unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P are herein collectively referred to as the "financial statements."
The combined notes to the financial statements have been prepared pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures included in annual financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations. The accompanying financial statements should be read in conjunction with the Combined Notes to Financial Statements included in Item 8, "Financial Statements and Supplementary Data," of the Eversource 2023 Form 10-K, which was filed with the SEC on February 14, 2024. 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, 2024 and December 31, 2023, and the results of operations, comprehensive income and common shareholders' equity for the three and six months ended June 30, 2024 and 2023, and the cash flows for the six months ended June 30, 2024 and 2023. The results of operations and comprehensive income for the three and six months ended June 30, 2024 and 2023 and the cash flows for the six months ended June 30, 2024 and 2023 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.
As of June 30, 2024, Eversource held several equity ownership interests that are not consolidated and are accounted for under the equity method, including 50 percent ownership interests in three offshore wind projects and a tax equity investment in one of the projects. See Note 1E, "Summary of Significant Accounting Policies – Investments in Unconsolidated Affiliates," for further information on Eversource’s equity method investments.
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.
17

Receivables are recorded at amortized cost, net of a credit loss provision (or allowance for uncollectible accounts). The current expected credit loss (CECL) model is applied to receivables for purposes of calculating the allowance for uncollectible accounts. This model is based on expected losses and results in the recognition of estimated expected credit losses, including uncollectible amounts for both billed and unbilled revenues, over the life of the receivable at the time a receivable is recorded.
The allowance for uncollectible accounts is determined based upon a variety of judgments and factors, including an aging-based quantitative assessment that applies an estimated uncollectible percentage to each receivable aging category. Factors in determining credit loss include historical collection, write-off experience, analysis of delinquency statistics, and management's assessment of collectability from customers, including current economic conditions, customer payment trends, the impact on customer bills because of energy usage trends and changes in rates, flexible payment plans and financial hardship arrearage management programs 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, 2024 adequately reflected the collection risk and net realizable value for its receivables.
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 th is as follows:

| Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
(Millions of Dollars) | Hardship Accounts |  | Retail (Non-Hardship), Wholesale, and Other |  | Total Allowance |  | Hardship Accounts |  | Retail (Non-Hardship), Wholesale, and Other |  | Total Allowance |  | Hardship Accounts |  | Retail (Non-Hardship), Wholesale, and Other |  | Total Allowance |  | Total Allowance
Three Months Ended 2024 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Beginning Balance | $ | 379.4 |  |  | $ | 190.7 |  |  | $ | 570.1 |  |  | $ | 271.8 |  |  | $ | 36.0 |  |  | $ | 307.8 |  |  | $ | 41.8 |  |  | $ | 55.9 |  |  | $ | 97.7 |  |  | $ | 13.8 |
Uncollectible Expense | — |  |  | 9.9 |  |  | 9.9 |  |  | — |  |  | 2.8 |  |  | 2.8 |  |  | — |  |  | 5.9 |  |  | 5.9 |  |  | 1.0 |
Uncollectible Costs Deferred (1) | 26.0 |  |  | 10.0 |  |  | 36.0 |  |  | 15.3 |  |  | 2.6 |  |  | 17.9 |  |  | 4.3 |  |  | 4.7 |  |  | 9.0 |  |  | 1.1 |
Write-Offs | (16.5) |  |  | (23.3) |  |  | (39.8) |  |  | (12.9) |  |  | (8.3) |  |  | (21.2) |  |  | (0.2) |  |  | (7.1) |  |  | (7.3) |  |  | (2.0) |
Recoveries Collected | 0.2 |  |  | 3.2 |  |  | 3.4 |  |  | 0.2 |  |  | 1.1 |  |  | 1.3 |  |  | — |  |  | 0.9 |  |  | 0.9 |  |  | 0.2 |
Ending Balance | $ | 389.1 |  |  | $ | 190.5 |  |  | $ | 579.6 |  |  | $ | 274.4 |  |  | $ | 34.2 |  |  | $ | 308.6 |  |  | $ | 45.9 |  |  | $ | 60.3 |  |  | $ | 106.2 |  |  | $ | 14.1 |
Six Months Ended 2024 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Beginning Balance | $ | 366.8 |  |  | $ | 187.7 |  |  | $ | 554.5 |  |  | $ | 259.7 |  |  | $ | 36.3 |  |  | $ | 296.0 |  |  | $ | 43.6 |  |  | $ | 53.4 |  |  | $ | 97.0 |  |  | $ | 14.3 |
Uncollectible Expense | — |  |  | 26.3 |  |  | 26.3 |  |  | — |  |  | 6.3 |  |  | 6.3 |  |  | — |  |  | 12.0 |  |  | 12.0 |  |  | 2.2 |
Uncollectible Costs Deferred (1) | 53.5 |  |  | 21.4 |  |  | 74.9 |  |  | 38.1 |  |  | 5.3 |  |  | 43.4 |  |  | 3.5 |  |  | 9.1 |  |  | 12.6 |  |  | 2.4 |
Write-Offs | (31.7) |  |  | (51.8) |  |  | (83.5) |  |  | (23.8) |  |  | (16.0) |  |  | (39.8) |  |  | (1.2) |  |  | (16.3) |  |  | (17.5) |  |  | (5.2) |
Recoveries Collected | 0.5 |  |  | 6.9 |  |  | 7.4 |  |  | 0.4 |  |  | 2.3 |  |  | 2.7 |  |  | — |  |  | 2.1 |  |  | 2.1 |  |  | 0.4 |
Ending Balance | $ | 389.1 |  |  | $ | 190.5 |  |  | $ | 579.6 |  |  | $ | 274.4 |  |  | $ | 34.2 |  |  | $ | 308.6 |  |  | $ | 45.9 |  |  | $ | 60.3 |  |  | $ | 106.2 |  |  | $ | 14.1 |

18

| 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 (2)
Three Months Ended 2023 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Beginning Balance | $ | 318.7 |  |  | $ | 216.4 |  |  | $ | 535.1 |  |  | $ | 216.2 |  |  | $ | 37.2 |  |  | $ | 253.4 |  |  | $ | 42.0 |  |  | $ | 52.6 |  |  | $ | 94.6 |  |  | $ | 33.5 |
Uncollectible Expense | — |  |  | 1.4 |  |  | 1.4 |  |  | — |  |  | 0.9 |  |  | 0.9 |  |  | — |  |  | 3.1 |  |  | 3.1 |  |  | (5.5) |
Uncollectible Costs Deferred (1) | 27.0 |  |  | (5.5) |  |  | 21.5 |  |  | 16.6 |  |  | 3.4 |  |  | 20.0 |  |  | 3.7 |  |  | 3.9 |  |  | 7.6 |  |  | (13.5) |
Write-Offs | (8.1) |  |  | (21.8) |  |  | (29.9) |  |  | (6.8) |  |  | (6.7) |  |  | (13.5) |  |  | (0.1) |  |  | (8.6) |  |  | (8.7) |  |  | (2.0) |
Recoveries Collected | 0.6 |  |  | 3.7 |  |  | 4.3 |  |  | 0.5 |  |  | 1.5 |  |  | 2.0 |  |  | — |  |  | 1.2 |  |  | 1.2 |  |  | 0.2 |
Ending Balance | $ | 338.2 |  |  | $ | 194.2 |  |  | $ | 532.4 |  |  | $ | 226.5 |  |  | $ | 36.3 |  |  | $ | 262.8 |  |  | $ | 45.6 |  |  | $ | 52.2 |  |  | $ | 97.8 |  |  | $ | 12.7 |
Six Months Ended 2023 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Beginning Balance | $ | 284.4 |  |  | $ | 201.9 |  |  | $ | 486.3 |  |  | $ | 188.9 |  |  | $ | 36.4 |  |  | $ | 225.3 |  |  | $ | 43.7 |  |  | $ | 51.3 |  |  | $ | 95.0 |  |  | $ | 29.2 |
Uncollectible Expense | — |  |  | 24.2 |  |  | 24.2 |  |  | — |  |  | 4.8 |  |  | 4.8 |  |  | — |  |  | 7.8 |  |  | 7.8 |  |  | (0.5) |
Uncollectible Costs Deferred (1) | 70.8 |  |  | 8.7 |  |  | 79.5 |  |  | 50.9 |  |  | 6.1 |  |  | 57.0 |  |  | 2.4 |  |  | 9.3 |  |  | 11.7 |  |  | (12.2) |
Write-Offs | (17.8) |  |  | (48.0) |  |  | (65.8) |  |  | (14.1) |  |  | (13.7) |  |  | (27.8) |  |  | (0.5) |  |  | (18.9) |  |  | (19.4) |  |  | (4.2) |
Recoveries Collected | 0.8 |  |  | 7.4 |  |  | 8.2 |  |  | 0.8 |  |  | 2.7 |  |  | 3.5 |  |  | — |  |  | 2.7 |  |  | 2.7 |  |  | 0.4 |
Ending Balance | $ | 338.2 |  |  | $ | 194.2 |  |  | $ | 532.4 |  |  | $ | 226.5 |  |  | $ | 36.3 |  |  | $ | 262.8 |  |  | $ | 45.6 |  |  | $ | 52.2 |  |  | $ | 97.8 |  |  | $ | 12.7 |

(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 increases in the allowance for uncollectible hardship accounts at Eversource and CL&P in both 2024 and 2023 primarily relate to increased customer enrollment in disconnection prevention programs in Connecticut.
(2) In connection with PSNH’s pole purchase agreement on May 1, 2023, the purchase price included the forgiveness of previously reserved receivables for reimbursement of operation and maintenance and vegetation management costs.
C. Fair Value Measurements
Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" (normal) and to marketable securities held in trusts. Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill, long-lived assets, equity method investments, AROs, and in the valuation of business combinations and asset acquisitions. The fair value measurement guidance was also applied in estimating the fair value of preferred stock, long-term debt and RRBs.
Fair Value Hierarchy: In measuring fair value, Eversource uses observable market data when available in order to minimize the use of unobservable inputs. Inputs used in fair value measurements are categorized into three fair value hierarchy levels for disclosure purposes. The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement. Eversource evaluates the classification of assets and liabilities measured at fair value on a quarterly basis.
The levels of the fair value hierarchy are described below:
Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable.
Level 3 - Quoted market prices are not available. Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable. Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products.
Uncategorized - Investments that are measured at net asset value are not categorized within the fair value hierarchy.
Determination of Fair Value: The valuation techniques and inputs used in Eversource's fair value measurements are described in Note 4, "Derivative Instruments," Note 5, "Marketable Securities," and Note 10, "Fair Value of Financial Instruments," to the financial statements.
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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, 2024 |  | June 30, 2023
(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 | $ | 30.0 |  |  | $ | 7.2 |  |  | $ | 13.3 |  |  | $ | 3.7 |  |  | $ | 33.3 |  |  | $ | 8.4 |  |  | $ | 14.1 |  |  | $ | 3.9 |
AFUDC Equity | 23.7 |  |  | 5.5 |  |  | 15.2 |  |  | 1.7 |  |  | 19.0 |  |  | 4.6 |  |  | 12.0 |  |  | 1.1 |
Equity in Earnings of Unconsolidated Affiliates (1) | 23.2 |  |  | — |  |  | 0.2 |  |  | — |  |  | 5.0 |  |  | — |  |  | 0.1 |  |  | — |
Investment Income/(Loss) | 1.1 |  |  | (0.1) |  |  | 0.5 |  |  | — |  |  | (1.4) |  |  | (1.1) |  |  | 0.3 |  |  | (0.3) |
Interest Income | 37.1 |  |  | 10.4 |  |  | 19.2 |  |  | 2.4 |  |  | 21.4 |  |  | 1.5 |  |  | 14.4 |  |  | 1.2 |
Other (2) | 0.2 |  |  | — |  |  | — |  |  | — |  |  | 17.6 |  |  | — |  |  | — |  |  | 0.4 |
Total Other Income, Net | $ | 115.3 |  |  | $ | 23.0 |  |  | $ | 48.4 |  |  | $ | 7.8 |  |  | $ | 94.9 |  |  | $ | 13.4 |  |  | $ | 40.9 |  |  | $ | 6.3 |
| For the Six Months Ended
| June 30, 2024 |  | June 30, 2023
(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 | $ | 57.8 |  |  | $ | 13.7 |  |  | $ | 25.6 |  |  | $ | 7.3 |  |  | $ | 68.1 |  |  | $ | 17.9 |  |  | $ | 28.8 |  |  | $ | 8.1 |
AFUDC Equity | 50.5 |  |  | 11.5 |  |  | 31.4 |  |  | 3.6 |  |  | 34.5 |  |  | 8.7 |  |  | 21.5 |  |  | 1.8 |
Equity in Earnings of Unconsolidated Affiliates (1) | 31.0 |  |  | — |  |  | 0.4 |  |  | — |  |  | 8.8 |  |  | — |  |  | 0.2 |  |  | — |
Investment Income/(Loss) | 0.3 |  |  | (0.9) |  |  | 0.9 |  |  | (0.2) |  |  | (3.1) |  |  | (1.7) |  |  | (0.2) |  |  | (0.4) |
Interest Income | 67.1 |  |  | 15.1 |  |  | 37.2 |  |  | 4.1 |  |  | 44.5 |  |  | 3.4 |  |  | 30.4 |  |  | 2.1 |
Other (2) | (0.4) |  |  | — |  |  | — |  |  | — |  |  | 31.1 |  |  | — |  |  | 0.1 |  |  | 0.4 |
Total Other Income, Net | $ | 206.3 |  |  | $ | 39.4 |  |  | $ | 95.5 |  |  | $ | 14.8 |  |  | $ | 183.9 |  |  | $ | 28.3 |  |  | $ | 80.8 |  |  | $ | 12.0 |

(1) Equity in Earnings of Unconsolidated Affiliates includes $23.4 million of pre-tax income recorded at Eversource in the second quarter of 2024 from Eversource’s wind equity method investment, North East Offshore, as a result of a vendor settlement agreement payment received by the joint venture. This settlement payment reduced the required capital contributions to be made by Eversource to North East Offshore during the second quarter of 2024.
(2) Eversource’s equity method investment in a renewable energy fund was liquidated in March 2023. Liquidation proceeds in excess of the carrying value were recorded in both the first and second quarters of 2023 within Other in the tables above. See Note 1E, "Summary of Significant Accounting Policies - Investments in Unconsolidated Affiliates," for further information.
E. Investments in Unconsolidated Affiliates
Investments in entities that are not consolidated are included in long-term assets on the balance sheets and earnings impacts from these equity investments are included in Other Income, Net on the statements of income. Eversource's investments included the following:

|  |  |  |  | Investment Balance
(Millions of Dollars) | Ownership Interest |  | As of June 30, 2024 |  | As of December 31, 2023
Offshore Wind Business | 50% | - | 100% |  | $ | 806.1 |  |  | $ | 515.5 |
Natural Gas Pipeline - Algonquin Gas Transmission, LLC | 15% |  | 113.2 |  |  | 116.0 |
Other | various |  | 29.7 |  |  | 29.0 |
Total Investments in Unconsolidated Affiliates |  |  |  |  | $ | 949.0 |  |  | $ | 660.5 |

Offshore Wind Business: As of June 30, 2024, Eversource’s offshore wind business includes 50 percent ownership interests in each of North East Offshore and South Fork Class B Member, LLC, which collectively hold three offshore wind projects. North East Offshore holds the Revolution Wind project and the Sunrise Wind project. South Fork Class B Member, LLC holds the South Fork Wind project. The offshore wind projects are being developed and constructed through joint and equal partnerships with Ørsted. Eversource’s offshore wind business also includes a noncontrolling tax equity investment in South Fork Wind through a 100 percent ownership in South Fork Wind Holdings, LLC Class A shares.
On May 25, 2023, Eversource announced that it had completed a strategic review of its offshore wind investments and determined that it would pursue the sale of its offshore wind investments. On September 7, 2023, Eversource completed the sale of its 50 percent interest in an uncommitted lease area consisting of approximately 175,000 developable acres located 25 miles off the south coast of Massachusetts to Ørsted for $625 million in an all-cash transaction.
In September of 2023, Eversource made a contribution of $528 million using the proceeds from the lease area sale to invest in a tax equity interest for South Fork Wind. South Fork Wind was restructured as a tax equity investment, with Eversource purchasing 100 percent ownership of a new Class A tax equity membership interest. This investment will result in Eversource receiving cash flow benefits from investment tax credits (ITC) and other future cash flow benefits as well. As of June 30 2024, all twelve South Fork Wind turbines met the requirements to qualify for the investment tax credits. As a result, $385 million of expected investment tax credits were reclassified from the South Fork Wind tax equity
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investment balance reported in Investments in Unconsolidated Affiliates as a reduction in current taxes payable of $54 million and an increase in deferred tax assets of $331 million on the Eversource balance sheet as of June 30, 2024.
As a result of these investment tax credits generated from our wind investments, Eversource expects lower federal income tax payments between 2024 through 2026.
Sales of Offshore Wind Investments: On January 24, 2024, Ørsted signed an agreement with Eversource to acquire Eversource’s 50 percent share of Sunrise Wind, subject to the successful selection of Sunrise Wind in the New York fourth solicitation for offshore wind capacity, signing of an OREC contract with NYSERDA, finalization of agreements including the equity and asset purchase agreement, receipt of the final approval by BOEM of the Sunrise Wind Construction and Operations Plan (COP), and relevant regulatory approvals. On February 29, 2024, Sunrise Wind was selected for contract negotiation in the offshore wind solicitation by NYSERDA, and was subsequently awarded a contract, which was finalized and completed on May 31, 2024. In June 2024, Sunrise Wind received final approval by BOEM of its COP and all remaining regulatory approvals.
On April 18, 2024, Eversource and Ørsted executed the equity and asset purchase agreement to sell Eversource’s 50 percent interest in Sunrise Wind to Ørsted for a gross purchase price of $230 million. The purchase price was subject to reduction for actual capital spending less than forecasted spending between signing the agreement in January and closing of the transaction. On July 9, 2024, Eversource completed the sale of its 50 percent ownership share of Sunrise Wind to Ørsted. In accordance with the equity and asset purchase agreement and after adjustment for the reduction in capital spending compared to forecasted, Ørsted paid Eversource $118 million at the closing of the sale transaction, and the remaining proceeds of $34 million will be paid after onshore construction is completed and certain other construction milestones are achieved.
With the completion of the sale, Eversource has divested all of its ownership interest in Sunrise Wind and will not have any ongoing ownership interest in the project, nor any ongoing financial obligations associated with project costs. Eversource’s existing credit support obligations were either terminated or indemnified by Ørsted as a result of the sale. Eversource has entered into a separate amended and restated construction management agreement to manage Sunrise Wind’s onshore construction through completion. In this role, Eversource will solely be a service provider to Sunrise Wind.
On February 13, 2024, Eversource executed an agreement to sell its existing 50 percent interests in the South Fork Wind and Revolution Wind projects to Global Infrastructure Partners (GIP) for $1.1 billion of cash proceeds to be received upon closing, subject to adjustment. The purchase price is inclusive of the sales value related to a 40 percent level of federal investment tax credits, 10 percent of which is the energy community ITC adder of approximately $170 million related to Revolution Wind. The purchase price is subject to adjustments based on, among other things, the progress, timing and the construction cost of Revolution Wind, including changes in actual versus forecasted capital spending between signing the agreement and closing of the transaction. Factors that could result in Eversource’s total net proceeds from the transaction to be lower, resulting in post-closing adjustment payments owed to GIP, include the ultimate cost of construction and extent of cost overruns for Revolution Wind, delays in constructing Revolution Wind, which would impact the economics associated with the purchase price adjustment, and Revolution Wind’s eligibility for federal investment tax credits at less than the value included in the purchase price. Total net proceeds could also be adjusted for a benefit due to Eversource if there are lower operation costs or higher availability of the projects through the period that is four years following the commercial operation date of the Revolution Wind project.
The post-closing purchase price adjustment payments include cost sharing obligations that provide Eversource will share equally with GIP in GIP’s funding obligations for up to approximately $240 million of incremental capital expenditure overruns incurred during the construction phase for Revolution Wind, after which obligations for any additional capital expenditure overruns would be shared equally by Eversource and Ørsted. The purchase price is also subject to post-closing adjustments as a result of final project economics, which includes Eversource’s obligation to maintain GIP’s internal rate of return for each project as specified in the agreement. Post-closing purchase price adjustment payments will be made following the sale closing date for South Fork and following the commercial operation of Revolution Wind. South Fork Wind construction has been completed, and Eversource does not expect any material cost sharing or other purchase price adjustment payments for South Fork Wind.
Closing the transaction with GIP is subject to customary conditions, including certain regulatory approvals, as well as other conditions, among which is the completion and execution of the partnership agreements between GIP and Ørsted that will govern GIP’s new ownership interest in those projects following Eversource’s divestiture. All regulatory approvals have been received and the review period under the Hart Scott Rodino Act has expired. Closing of this transaction is currently expected to occur in the third quarter of 2024.
Under the agreement with GIP, Eversource’s existing credit support obligations are expected to roll off for each project around the time that each project completes its expected capital spend. Eversource will continue to make future cash expenditures for required cash contributions up to the time of disposition of the Revolution Wind and South Fork Wind projects and changes in the timing and amounts of these contributions would be adjusted in the purchase price.
Upon close of the sale transactions in the third quarter of 2024, the total proceeds will be compared to the current carrying value of the investments, and the difference will be reflected in the statement of income. At that time, Eversource will also record an estimate of future obligations under the terms of the GIP transaction, which primarily could include the potential cost overrun sharing obligation and potential obligation to maintain GIP’s internal rate of return for the Revolution Wind project. Eversource is currently evaluating the combined impact of the Sunrise Wind sale and the expected sale of Revolution Wind and South Fork Wind, and at this time, does not expect a material financial impact on our 2024 results. Proceeds from the transactions will be used to pay off parent company debt.
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Impairment: Equity method investments are assessed for impairment when conditions exist as of the balance sheet date that indicate that the fair value of the investment may be 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. If the decline in value is considered to be other-than-temporary, the investment is written down to its estimated fair value, which establishes a new cost basis in the investment. Subsequent declines or recoveries after the reporting date are not considered in the impairment recognized. Investments that are other-than-temporarily impaired and written down to their estimated fair value cannot subsequently be written back up for increases in estimated fair value. Impairment evaluations involve a significant degree of judgment and estimation, including identifying circumstances that indicate an impairment may exist at the equity method investment level, selecting discount rates used to determine fair values, and developing an estimate of discounted future cash flows expected from investment operations or the sale of the investment. In the second quarter of 2024, there were no indicators of an other-than-temporary impairment in Eversource’s equity method investment balance.
In the second quarter of 2023, in connection with the process to divest its offshore wind business, Eversource identified indicators for impairment. In the impairment assessment, Eversource evaluated its investments and determined that the carrying value of the equity method offshore wind investments exceeded the fair value of the investments and that the decline in fair value was other-than-temporary. The completion of the strategic review in the second quarter of 2023 resulted in Eversource recording a pre-tax other-than-temporary impairment charge of $401 million ($331 million after-tax) to reflect the investment at estimated fair value based on the expected purchase price at that time. In the fourth quarter of 2023, Eversource recognized an additional pre-tax other-than-temporary impairment charge of $1.77 billion ($1.62 billion after-tax) in its offshore wind investments and established a new cost basis in the investments as of December 31, 2023. The impairment charges were non-cash charges and did not impact Eversource’s cash position.
2023 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 of $147.0 million were included in Investments in Unconsolidated Affiliates within investing activities on the statement of cash flows for the six months ended June 30, 2023. Of this amount, $123.4 million was received in the first quarter of 2023, and $23.6 million was received from escrow in the second quarter of 2023. A portion of the proceeds was 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 received in excess of the investment’s carrying value and the 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
(Millions of Dollars) | June 30, 2024 |  | June 30, 2023 |  | June 30, 2024 |  | June 30, 2023
Eversource | $ | 44.6 |  |  | $ | 44.7 |  |  | $ | 97.9 |  |  | $ | 99.7 |
CL&P | 39.7 |  |  | 38.9 |  |  | 83.6 |  |  | 82.0

As agents for state and local governments, Eversource's companies that serve customers in Connecticut and Massachusetts collect certain sales taxes that are recorded on a net basis with no impact on the statements of income.
G. Supplemental Cash Flow Information
Non-cash investing activities include plant additions included in Accounts Payable as follows:

(Millions of Dollars) | As of June 30, 2024 |  | As of June 30, 2023
Eversource | $ | 477.9 |  |  | $ | 457.5 |
CL&P | 89.2 |  |  | 104.8 |
NSTAR Electric | 142.2 |  |  | 113.4 |
PSNH | 86.5 |  |  | 59.6 |

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

| As of June 30, 2024 |  | As of December 31, 2023
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Cash as reported on the Balance Sheets | $ | 33.4 |  |  | $ | — |  |  | $ | 2.7 |  |  | $ | 0.3 |  |  | $ | 53.9 |  |  | $ | 10.2 |  |  | $ | 6.7 |  |  | $ | 0.2 |
Restricted cash included in: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Special Deposits | 66.4 |  |  | 1.1 |  |  | 1.4 |  |  | 30.6 |  |  | 81.5 |  |  | 2.0 |  |  | 16.1 |  |  | 31.6 |
Marketable Securities | 16.3 |  |  | — |  |  | — |  |  | — |  |  | 13.7 |  |  | — |  |  | — |  |  | — |
Other Long-Term Assets | 16.5 |  |  | — |  |  | — |  |  | 3.2 |  |  | 17.3 |  |  | — |  |  | — |  |  | 3.2 |
Cash and Restricted Cash as reported on the Statements of Cash Flows | $ | 132.6 |  |  | $ | 1.1 |  |  | $ | 4.1 |  |  | $ | 34.1 |  |  | $ | 166.4 |  |  | $ | 12.2 |  |  | $ | 22.8 |  |  | $ | 35.0 |

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Special Deposits represent cash collections related to the PSNH RRB customer charges that are held in trust, required ISO-NE cash deposits, cash held in escrow accounts, and CYAPC and YAEC cash balances. Special Deposits are included in Current Assets on the balance sheets. Restricted cash included in Marketable Securities represents money market funds held in restricted trusts to fund CYAPC and YAEC's spent nuclear fuel storage obligations.
Eversource’s restricted cash includes an Energy Relief Fund for energy efficiency and clean energy measures in the Merrimack Valley established under the terms of the EGMA 2020 settlement agreement. This restricted cash held in escrow accounts included $20.0 million recorded as short-term in Special Deposits as of both June 30, 2024 and December 31, 2023, and $13.3 million and $14.1 million recorded in Other Long-Term Assets on the balance sheets as of June 30, 2024 and December 31, 2023, 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, 2024 |  | As of December 31, 2023
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Storm Costs, Net | $ | 2,074.8 |  |  | $ | 976.8 |  |  | $ | 652.1 |  |  | $ | 445.9 |  |  | $ | 1,785.9 |  |  | $ | 896.6 |  |  | $ | 609.1 |  |  | $ | 280.2 |
Regulatory Tracking Mechanisms | 1,722.0 |  |  | 743.7 |  |  | 549.6 |  |  | 174.3 |  |  | 1,319.2 |  |  | 354.5 |  |  | 482.9 |  |  | 182.2 |
Benefit Costs | 1,116.5 |  |  | 201.6 |  |  | 320.3 |  |  | 81.0 |  |  | 1,117.3 |  |  | 197.4 |  |  | 336.7 |  |  | 79.3 |
Income Taxes, Net | 936.1 |  |  | 522.4 |  |  | 138.2 |  |  | 14.8 |  |  | 912.4 |  |  | 512.6 |  |  | 128.6 |  |  | 16.4 |
Securitized Stranded Costs | 370.9 |  |  | — |  |  | — |  |  | 370.9 |  |  | 392.5 |  |  | — |  |  | — |  |  | 392.5 |
Goodwill-related | 255.7 |  |  | — |  |  | 219.5 |  |  | — |  |  | 264.1 |  |  | — |  |  | 226.7 |  |  | — |
Asset Retirement Obligations | 144.0 |  |  | 39.8 |  |  | 75.3 |  |  | 4.9 |  |  | 137.9 |  |  | 38.5 |  |  | 72.3 |  |  | 4.7 |
Derivative Liabilities | 87.4 |  |  | 87.4 |  |  | — |  |  | — |  |  | 120.9 |  |  | 120.9 |  |  | — |  |  | — |
Other Regulatory Assets | 360.3 |  |  | 21.0 |  |  | 107.9 |  |  | 5.8 |  |  | 339.0 |  |  | 22.7 |  |  | 101.6 |  |  | 8.0 |
Total Regulatory Assets | 7,067.7 |  |  | 2,592.7 |  |  | 2,062.9 |  |  | 1,097.6 |  |  | 6,389.2 |  |  | 2,143.2 |  |  | 1,957.9 |  |  | 963.3 |
Less: Current Portion | 2,071.7 |  |  | 860.8 |  |  | 757.4 |  |  | 175.0 |  |  | 1,674.2 |  |  | 480.4 |  |  | 676.1 |  |  | 189.5 |
Total Long-Term Regulatory Assets | $ | 4,996.0 |  |  | $ | 1,731.9 |  |  | $ | 1,305.5 |  |  | $ | 922.6 |  |  | $ | 4,715.0 |  |  | $ | 1,662.8 |  |  | $ | 1,281.8 |  |  | $ | 773.8 |

Regulatory Costs in Other Long-Term Assets: Eversource's regulated companies had $267.0 million (including $180.4 million for CL&P, $27.8 million for NSTAR Electric and $2.1 million for PSNH) and $241.7 million (including $166.7 million for CL&P, $21.9 million for NSTAR Electric and $1.2 million for PSNH) of additional regulatory costs not yet specifically approved as of June 30, 2024 and December 31, 2023, respectively, that were included in Other Long-Term Assets on the balance sheets. These amounts will be reclassified to Regulatory Assets upon approval by the applicable regulatory agency. 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, 2024 and December 31, 2023, these regulatory costs included $87.5 million (including $64.7 million for CL&P and $10.9 million for NSTAR Electric) and $82.1 million (including $64.0 million for CL&P and $7.3 million for NSTAR Electric), respectively, of deferred uncollectible hardship costs.
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Regulatory Liabilities: The components of regulatory liabilities were as follows:

| As of June 30, 2024 |  | As of December 31, 2023
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
EDIT due to Tax Cuts and Jobs Act of 2017 | $ | 2,526.7 |  |  | $ | 963.9 |  |  | $ | 894.0 |  |  | $ | 335.7 |  |  | $ | 2,548.6 |  |  | $ | 969.2 |  |  | $ | 905.1 |  |  | $ | 339.3 |
Regulatory Tracking Mechanisms | 722.7 |  |  | 183.2 |  |  | 393.3 |  |  | 72.6 |  |  | 668.3 |  |  | 154.0 |  |  | 347.2 |  |  | 114.4 |
Cost of Removal | 717.4 |  |  | 182.1 |  |  | 442.2 |  |  | 18.4 |  |  | 666.6 |  |  | 157.9 |  |  | 420.9 |  |  | 16.2 |
Deferred Portion of Non-Service Income Components of Pension, SERP and PBOP | 391.5 |  |  | 56.0 |  |  | 194.0 |  |  | 39.7 |  |  | 354.0 |  |  | 49.9 |  |  | 175.9 |  |  | 36.6 |
AFUDC - Transmission | 142.4 |  |  | 61.0 |  |  | 81.4 |  |  | — |  |  | 124.3 |  |  | 56.1 |  |  | 68.2 |  |  | — |
Benefit Costs | 40.4 |  |  | 0.5 |  |  | 14.7 |  |  | — |  |  | 51.0 |  |  | 0.6 |  |  | 22.2 |  |  | — |
Other Regulatory Liabilities | 204.0 |  |  | 38.5 |  |  | 13.5 |  |  | 4.9 |  |  | 201.9 |  |  | 30.4 |  |  | 13.9 |  |  | 4.6 |
Total Regulatory Liabilities | 4,745.1 |  |  | 1,485.2 |  |  | 2,033.1 |  |  | 471.3 |  |  | 4,614.7 |  |  | 1,418.1 |  |  | 1,953.4 |  |  | 511.1 |
Less: Current Portion | 652.3 |  |  | 133.3 |  |  | 413.5 |  |  | 79.1 |  |  | 591.8 |  |  | 102.2 |  |  | 368.1 |  |  | 117.5 |
Total Long-Term Regulatory Liabilities | $ | 4,092.8 |  |  | $ | 1,351.9 |  |  | $ | 1,619.6 |  |  | $ | 392.2 |  |  | $ | 4,022.9 |  |  | $ | 1,315.9 |  |  | $ | 1,585.3 |  |  | $ | 393.6 |

3. PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION
The following tables summarize property, plant and equipment by asset category:

Eversource | As of June 30, 2024 |  | As of December 31, 2023
(Millions of Dollars) |
Distribution - Electric | $ | 20,467.3 |  |  | $ | 19,656.5 |
Distribution - Natural Gas | 8,358.9 |  |  | 8,155.3 |
Transmission - Electric | 15,589.6 |  |  | 14,666.8 |
Distribution - Water | 2,313.5 |  |  | 2,280.1 |
Solar | 201.1 |  |  | 201.1 |
Utility | 46,930.4 |  |  | 44,959.8 |
Other (1) | 2,193.6 |  |  | 2,006.8 |
Property, Plant and Equipment, Gross | 49,124.0 |  |  | 46,966.6 |
Less: Accumulated Depreciation |  |  |
Utility | (10,110.4) |  |  | (9,670.1) |
Other | (964.4) |  |  | (869.6) |
Total Accumulated Depreciation | (11,074.8) |  |  | (10,539.7) |
Property, Plant and Equipment, Net | 38,049.2 |  |  | 36,426.9 |
Construction Work in Progress | 3,077.0 |  |  | 3,071.7 |
Total Property, Plant and Equipment, Net | $ | 41,126.2 |  |  | $ | 39,498.6 |

| As of June 30, 2024 |  | As of December 31, 2023
(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH |  | CL&P |  | NSTAR Electric |  | PSNH
Distribution - Electric | $ | 8,270.0 |  |  | $ | 9,378.4 |  |  | $ | 2,859.1 |  |  | $ | 7,897.1 |  |  | $ | 9,000.5 |  |  | $ | 2,799.2 |
Transmission - Electric | 6,790.7 |  |  | 6,146.5 |  |  | 2,654.1 |  |  | 6,548.2 |  |  | 5,630.8 |  |  | 2,489.5 |
Solar | — |  |  | 201.1 |  |  | — |  |  | — |  |  | 201.1 |  |  | — |
Property, Plant and Equipment, Gross | 15,060.7 |  |  | 15,726.0 |  |  | 5,513.2 |  |  | 14,445.3 |  |  | 14,832.4 |  |  | 5,288.7 |
Less: Accumulated Depreciation | (2,884.4) |  |  | (3,706.6) |  |  | (1,016.5) |  |  | (2,670.5) |  |  | (3,585.9) |  |  | (984.0) |
Property, Plant and Equipment, Net | 12,176.3 |  |  | 12,019.4 |  |  | 4,496.7 |  |  | 11,774.8 |  |  | 11,246.5 |  |  | 4,304.7 |
Construction Work in Progress | 512.3 |  |  | 1,303.5 |  |  | 336.7 |  |  | 565.4 |  |  | 1,507.3 |  |  | 270.0 |
Total Property, Plant and Equipment, Net | $ | 12,688.6 |  |  | $ | 13,322.9 |  |  | $ | 4,833.4 |  |  | $ | 12,340.2 |  |  | $ | 12,753.8 |  |  | $ | 4,574.7 |

(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.
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Derivative contracts that are not designated as normal are recorded at fair value as derivative assets or 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, 2024 |  | As of December 31, 2023
CL&P (Millions of Dollars) | Fair Value Hierarchy |  | Commodity Supply and Price Risk Management |  | Netting (1) |  | Net Amount Recorded as a Derivative |  | Commodity Supply and Price Risk Management |  | Netting (1) |  | Net Amount Recorded as a Derivative
Current Derivative Assets | Level 2 |  | $ | 15.5 |  |  | $ | (0.4) |  |  | $ | 15.1 |  |  | $ | 16.4 |  |  | $ | (0.5) |  |  | $ | 15.9 |
Long-Term Derivative Assets | Level 2 |  | 6.2 |  |  | (0.2) |  |  | 6.0 |  |  | 13.6 |  |  | (0.5) |  |  | 13.1 |
Current Derivative Liabilities | Level 2 |  | (77.4) |  |  | — |  |  | (77.4) |  |  | (81.9) |  |  | — |  |  | (81.9) |
Long-Term Derivative Liabilities | Level 2 |  | (31.1) |  |  | — |  |  | (31.1) |  |  | (68.0) |  |  | — |  |  | (68.0) |

(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 June 30, 2024 and December 31, 2023 were 615 MW and 682 MW, respectively. 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, 2024 and 2023, there were losses of $1.9 million and gains of $1.8 million, respectively. For the six months ended June 30, 2024 and 2023, there were losses of $2.9 million and $0.1 million, respectively. These changes in fair value associated with CL&P’s derivative contracts are deferred in Regulatory Assets on the balance sheet.
Fair Value Measurements of Derivative Instruments
The fair value of derivative contracts utilizes both 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 capacity 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 were prepared by individuals with expertise in valuation techniques, pricing of energy-related products, and accounting requirements. All derivative contracts were classified as Level 2 in the fair value hierarchy as of both June 30, 2024 and December 31, 2023.
The following table presents changes in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis. The derivative assets and liabilities are presented on a net basis.

CL&P |  |  | For the Three Months Ended June 30, 2023 |  | For the Six Months Ended June 30, 2023
(Millions of Dollars) |  |  |  |  |
Derivatives, Net: |  |  |  |  |  |  |
Fair Value as of Beginning of Period |  |  |  |  | $ | (168.8) |  |  | $ | (181.8) |
Net Realized/Unrealized Gains/(Losses) Included in Regulatory Assets |  |  |  |  | 1.8 |  |  | (0.1) |
Settlements |  |  |  |  | 14.9 |  |  | 29.8 |
Fair Value as of End of Period |  |  |  |  | $ | (152.1) |  |  | $ | (152.1) |

5. MARKETABLE SECURITIES
Eversource’s marketable securities 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. Eversource also holds trusts that are not subject to regulatory oversight by state or federal agencies that are primarily used to fund certain non-qualified executive benefits. The marketable securities within the non-qualified executive benefit trusts were sold in 2023. 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. CYAPC and YAEC’s spent nuclear fuel trusts are restricted and are classified in long-term Marketable Securities on the balance sheets.
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Equity Securities: Eversource's equity securities include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of $168.8 million and $173.6 million as of June 30, 2024 and December 31, 2023, 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.
Unrealized gains and losses on equity securities held in Eversource's trusts are recorded in Other Income, Net on the statements of income. The equity securities within Eversource’s non-qualified executive benefits trusts were sold during 2023. The fair value of equity securities held in Eversource’s trusts as of June 30, 2024 and December 31, 2023 were $3.8 million and $3.3 million, respectively. There were unrealized gains of $0.1 million and $0.5 million for the three and six months ended June 30, 2024 and unrealized losses of $4.7 million and $3.9 million for the three and six months ended June 30, 2023 recorded in Other Income, Net, respectively, related to these equity securities.
Available-for-Sale Debt Securities: The following is a summary of available-for-sale debt securities, which are held in CYAPC’s and YAEC’s spent nuclear fuel trusts:

| As of June 30, 2024 |  | As of December 31, 2023
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 | $ | 172.8 |  |  | $ | 0.2 |  |  | $ | (10.0) |  |  | $ | 163.0 |  |  | $ | 169.5 |  |  | $ | 1.4 |  |  | $ | (6.6) |  |  | $ | 164.3 |

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.
The debt securities within Eversource’s non-qualified executive benefits trusts were sold during 2023. Any unrealized gains and losses on available-for-sale debt securities held in Eversource's trusts are recorded in Accumulated Other Comprehensive Income, excluding amounts related to credit losses or losses on securities intended to be sold, which are recorded in Other Income, Net. There were no credit losses for the three and six months ended June 30, 2024 and 2023, and no allowance for credit losses as of June 30, 2024. 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.
As of June 30, 2024, the contractual maturities of available-for-sale debt securities were as follows:

Eversource (Millions of Dollars) | Amortized Cost |  | Fair Value
Less than one year | $ | 17.8 |  |  | $ | 17.7 |
One to five years | 30.9 |  |  | 30.3 |
Six to ten years | 43.9 |  |  | 42.5 |
Greater than ten years | 80.2 |  |  | 72.5 |
Total Debt Securities | $ | 172.8 |  |  | $ | 163.0 |

Realized Gains and Losses: Realized gains and losses are offset in long-term liabilities for CYAPC and YAEC and are recorded in Other Income, Net for Eversource's benefit trusts. Eversource utilizes the average cost basis method for the CYAPC and YAEC spent nuclear fuel trusts and the specific identification basis method for the Eversource non-qualified benefit 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, 2024 |  | As of December 31, 2023
Level 1: |  |  |
Mutual Funds and Equities | $ | 172.6 |  |  | $ | 176.9 |
Money Market Funds | 16.3 |  |  | 13.7 |
Total Level 1 | $ | 188.9 |  |  | $ | 190.6 |
Level 2: |  |  |
U.S. Government Issued Debt Securities (Agency and Treasury) | $ | 87.6 |  |  | $ | 90.1 |
Corporate Debt Securities | 33.5 |  |  | 34.0 |
Asset-Backed Debt Securities | 8.3 |  |  | 5.6 |
Municipal Bonds | 7.0 |  |  | 9.8 |
Other Fixed Income Securities | 10.3 |  |  | 11.1 |
Total Level 2 | $ | 146.7 |  |  | $ | 150.6 |
Total Marketable Securities | $ | 335.6 |  |  | $ | 341.2 |

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U.S. government issued debt securities are valued using market approaches that incorporate transactions for the same or similar bonds and adjustments for yields and maturity dates. Corporate debt securities are valued using a market approach, utilizing recent trades of the same or similar 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 13, 2028. 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 13, 2028, that 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
| June 30, 2024 |  | December 31, 2023 |  | June 30, 2024 |  | December 31, 2023 |  | June 30, 2024 |  | December 31, 2023
(Millions of Dollars) |  |  |  |  |
Eversource Parent Commercial Paper Program | $ | 1,203.0 |  |  | $ | 1,771.9 |  |  | $ | 797.0 |  |  | $ | 228.1 |  |  | 5.67 | % |  | 5.60 | %
NSTAR Electric Commercial Paper Program | 236.5 |  |  | 365.8 |  |  | 413.5 |  |  | 284.2 |  |  | 5.37 | % |  | 5.40 | %

There were no borrowings outstanding on the revolving credit facilities as of June 30, 2024 or December 31, 2023.
CL&P and PSNH have uncommitted line of credit agreements totaling $375 million and $250 million, respectively, all of which will expire in either October 2024, May 2025 or September 2025. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of June 30, 2024.
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 CL&P long-term debt issuance in January 2024, $207.3 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt on Eversource parent’s balance sheet as of December 31, 2023. As a result of the Yankee Gas long-term debt issuances in July 2024, $37.9 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2024.
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, 2024, there were intercompany loans from Eversource parent to CL&P of $407.8 million and to PSNH of $132.0 million. As of December 31, 2023, there were intercompany loans from Eversource parent to CL&P of $457.0 million and to PSNH of $233.0 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time. As a result of the CL&P long-term debt issuance in January 2024, $207.3 million of CL&P’s intercompany borrowings were reclassified to Long-Term Debt on CL&P’s balance sheet as of December 31, 2023.
Sources and Uses of Cash: The Company expects the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.
Long-Term Debt Issuance Authorizations: On February 8, 2024, the NHPUC approved PSNH’s request for authorization to issue up to $300 million in long-term debt through December 31, 2024. On May 1, 2024, the DPU approved NSTAR Electric’s request for authorization to issue up to $2.4 billion in long-term debt through December 31, 2026. On July 24, 2024, PURA approved CL&P’s request for authorization to issue up to $1.0 billion in long-term debt through December 31, 2025.
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Long-Term Debt Issuances and Repayments: The following table summarizes long-term debt issuances and repayments:

(Millions of Dollars) | Interest Rate |  | Issuance/(Repayment) |  | Issue Date or Repayment Date |  | Maturity Date |  | Use of Proceeds for Issuance/ Repayment Information
CL&P 2024 Series A First Mortgage Bonds | 4.65 | % |  | $ | 350.0 |  |  | January 2024 |  | January 2029 |  | Repaid short-term debt, paid capital expenditures and working capital
NSTAR Electric 2024 Debentures | 5.40 | % |  | 600.0 |  |  | May 2024 |  | June 2034 |  | Repaid short-term debt, paid capital expenditures and working capital
PSNH Series X First Mortgage Bonds | 5.35 | % |  | 300.0 |  |  | April 2024 |  | October 2033 |  | Repaid short-term debt, paid capital expenditures and working capital
Eversource Parent Series DD Senior Notes | 5.00 | % |  | 350.0 |  |  | January 2024 |  | January 2027 |  | Repaid short-term debt
Eversource Parent Series EE Senior Notes | 5.50 | % |  | 650.0 |  |  | January 2024 |  | January 2034 |  | Repaid short-term debt
Eversource Parent Series FF Senior Notes | 5.85 | % |  | 700.0 |  |  | April 2024 |  | April 2031 |  | Repay Series X Senior Notes and Aquarion’s 2014 Senior Notes at maturity and short-term debt
Eversource Parent Series GG Senior Notes | 5.95 | % |  | 700.0 |  |  | April 2024 |  | July 2034 |  | Repay Series X Senior Notes and Aquarion’s 2014 Senior Notes at maturity and short-term debt
Eversource Parent Series X Senior Notes | 4.20 | % |  | (900.0) |  |  | June 2024 |  | June 2024 |  | Paid at maturity
NSTAR Gas Series W First Mortgage Bonds | 5.29 | % |  | 160.0 |  |  | June 2024 |  | June 2029 |  | Repaid short-term debt, paid capital expenditures and general corporate purchases
NSTAR Gas Series X First Mortgage Bonds | 5.48 | % |  | 40.0 |  |  | June 2024 |  | June 2034 |  | Repaid short-term debt, paid capital expenditures and general corporate purchases
Yankee Gas Series W First Mortgage Bonds | 5.50 | % |  | 90.0 |  |  | July 2024 |  | July 2029 |  | Repaid short-term debt, paid capital expenditures, working capital and repay Series P bonds at maturity
Yankee Gas Series X First Mortgage Bonds | 5.74 | % |  | 90.0 |  |  | July 2024 |  | July 2034 |  | Repaid short-term debt, paid capital expenditures, working capital and repay Series P bonds at maturity

As a result of the Yankee Gas long-term debt issuances in July 2024, $100.0 million of current portion of long-term debt was reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2024.
7. RATE REDUCTION BONDS AND VARIABLE INTEREST ENTITIES
Rate Reduction Bonds: In May 2018, PSNH Funding, a wholly-owned subsidiary of PSNH, issued $635.7 million of securitized RRBs in multiple tranches with a weighted average interest rate of 3.66 percent, and final maturity dates ranging from 2026 to 2035. The RRBs are expected to be repaid by February 1, 2033. RRB payments consist of principal and interest and are paid semi-annually, beginning on February 1, 2019. The RRBs were issued pursuant to a finance order issued by the NHPUC in January 2018 to recover remaining costs resulting from the divestiture of PSNH’s generation assets.
PSNH Funding was formed solely to issue RRBs to finance PSNH's unrecovered remaining costs associated with the divestiture of its generation assets. PSNH Funding is considered a VIE primarily because the equity capitalization is insufficient to support its operations. PSNH has the power to direct the significant activities of the VIE and is most closely associated with the VIE as compared to other interest holders. Therefore, PSNH is considered the primary beneficiary and consolidates PSNH Funding in its consolidated financial statements.
The following tables summarize the impact of PSNH Funding on PSNH's balance sheets and income statements:

(Millions of Dollars) |  |  |
PSNH Balance Sheets: | As of June 30, 2024 |  | As of December 31, 2023
Restricted Cash - Current Portion (included in Special Deposits) | $ | 29.0 |  |  | $ | 30.0 |
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets) | 3.2 |  |  | 3.2 |
Securitized Stranded Cost (included in Regulatory Assets) | 370.9 |  |  | 392.5 |
Other Regulatory Liabilities (included in Regulatory Liabilities) | 4.7 |  |  | 5.3 |
Accrued Interest (included in Other Current Liabilities) | 6.1 |  |  | 6.3 |
Rate Reduction Bonds - Current Portion | 43.2 |  |  | 43.2 |
Rate Reduction Bonds - Long-Term Portion | 345.7 |  |  | 367.3 |

(Millions of Dollars) PSNH Income Statements: | For the Three Months Ended |  | For the Six Months Ended
June 30, 2024 |  | June 30, 2023 |  | June 30, 2024 |  | June 30, 2023
Amortization of RRB Principal (included in Amortization of Regulatory Assets/(Liabilities), Net) | $ | 10.8 |  |  | $ | 10.8 |  |  | $ | 21.6 |  |  | $ | 21.6 |
Interest Expense on RRB Principal (included in Interest Expense) | 3.6 |  |  | 3.9 |  |  | 7.3 |  |  | 8.0 |

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8. PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION
Eversource provides defined benefit retirement plans (Pension Plans) that cover eligible employees. In addition to the Pension Plans, Eversource maintains non-qualified defined benefit retirement plans (SERP Plans), which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees. Eversource also provides defined benefit postretirement plans (PBOP Plans) that provide life insurance and a health reimbursement arrangement created for the purpose of reimbursing retirees and dependents for health insurance premiums and certain medical expenses to eligible employees that meet certain age and service eligibility requirements.
The components of net periodic benefit plan expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets/(liabilities) for future recovery or refund, are shown below. The service cost component of net periodic benefit plan expense/(income), less the capitalized portion, is included in Operations and Maintenance expense on the statements of income. The remaining components of net periodic benefit plan expense/(income), less the deferred portion, are included in Other Income, Net on the statements of income. Pension, SERP and PBOP expense reflected in the statements of cash flows for CL&P, NSTAR Electric and PSNH does not include intercompany allocations of net periodic benefit plan expense/(income), as these amounts are cash settled on a short-term basis.

| Pension and SERP |  | PBOP
| For the Three Months Ended June 30, 2024 |  | For the Three Months Ended June 30, 2024
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Service Cost | $ | 11.2 |  |  | $ | 3.3 |  |  | $ | 1.9 |  |  | $ | 1.1 |  |  | $ | 1.8 |  |  | $ | 0.3 |  |  | $ | 0.3 |  |  | $ | 0.2 |
Interest Cost | 62.7 |  |  | 12.7 |  |  | 12.8 |  |  | 6.7 |  |  | 8.0 |  |  | 1.4 |  |  | 2.2 |  |  | 0.8 |
Expected Return on Plan Assets | (115.7) |  |  | (23.5) |  |  | (28.0) |  |  | (12.2) |  |  | (20.3) |  |  | (2.3) |  |  | (9.9) |  |  | (1.4) |
Actuarial Loss/(Gain) | 22.1 |  |  | 3.2 |  |  | 6.4 |  |  | 1.3 |  |  | (0.1) |  |  | — |  |  | — |  |  | — |
Prior Service Cost/(Credit) | 0.3 |  |  | — |  |  | 0.1 |  |  | — |  |  | (5.4) |  |  | 0.2 |  |  | (4.3) |  |  | 0.1 |
Total Net Periodic Benefit Plan Income | $ | (19.4) |  |  | $ | (4.3) |  |  | $ | (6.8) |  |  | $ | (3.1) |  |  | $ | (16.0) |  |  | $ | (0.4) |  |  | $ | (11.7) |  |  | $ | (0.3) |
Intercompany Income Allocations | N/A |  | $ | (0.6) |  |  | $ | (0.6) |  |  | $ | (0.2) |  |  | N/A |  | $ | (0.5) |  |  | $ | (0.6) |  |  | $ | (0.2) |
| Pension and SERP |  | PBOP
| For the Six Months Ended June 30, 2024 |  | For the Six Months Ended June 30, 2024
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Service Cost | $ | 22.0 |  |  | $ | 6.2 |  |  | $ | 4.0 |  |  | $ | 2.1 |  |  | $ | 3.5 |  |  | $ | 0.6 |  |  | $ | 0.6 |  |  | $ | 0.3 |
Interest Cost | 124.7 |  |  | 25.1 |  |  | 25.9 |  |  | 13.4 |  |  | 16.0 |  |  | 2.8 |  |  | 4.4 |  |  | 1.7 |
Expected Return on Plan Assets | (231.3) |  |  | (46.8) |  |  | (56.3) |  |  | (24.4) |  |  | (40.7) |  |  | (4.7) |  |  | (19.8) |  |  | (2.8) |
Actuarial Loss/(Gain) | 41.9 |  |  | 5.7 |  |  | 12.8 |  |  | 2.4 |  |  | (0.2) |  |  | — |  |  | — |  |  | — |
Prior Service Cost/(Credit) | 0.6 |  |  | — |  |  | 0.2 |  |  | — |  |  | (10.8) |  |  | 0.5 |  |  | (8.5) |  |  | 0.2 |
Settlement Loss | 4.3 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Total Net Periodic Benefit Plan Income | $ | (37.8) |  |  | $ | (9.8) |  |  | $ | (13.4) |  |  | $ | (6.5) |  |  | $ | (32.2) |  |  | $ | (0.8) |  |  | $ | (23.3) |  |  | $ | (0.6) |
Intercompany Income Allocations | N/A |  | $ | (0.3) |  |  | $ | (0.2) |  |  | $ | (0.1) |  |  | N/A |  | $ | (1.1) |  |  | $ | (1.3) |  |  | $ | (0.4) |
| Pension and SERP |  | PBOP
| For the Three Months Ended June 30, 2023 |  | For the Three Months Ended June 30, 2023
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Service Cost | $ | 10.7 |  |  | $ | 3.1 |  |  | $ | 1.9 |  |  | $ | 1.1 |  |  | $ | 2.0 |  |  | $ | 0.3 |  |  | $ | 0.3 |  |  | $ | 0.2 |
Interest Cost | 63.5 |  |  | 12.7 |  |  | 13.5 |  |  | 6.8 |  |  | 8.4 |  |  | 1.5 |  |  | 2.3 |  |  | 0.9 |
Expected Return on Plan Assets | (116.5) |  |  | (23.7) |  |  | (28.5) |  |  | (12.5) |  |  | (19.5) |  |  | (2.3) |  |  | (9.3) |  |  | (1.4) |
Actuarial Loss | 11.6 |  |  | 0.6 |  |  | 4.0 |  |  | 0.4 |  |  | — |  |  | — |  |  | — |  |  | — |
Prior Service Cost/(Credit) | 0.3 |  |  | — |  |  | 0.1 |  |  | — |  |  | (5.4) |  |  | 0.3 |  |  | (4.3) |  |  | 0.1 |
Settlement Loss | 3.7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Total Net Periodic Benefit Plan Income | $ | (26.7) |  |  | $ | (7.3) |  |  | $ | (9.0) |  |  | $ | (4.2) |  |  | $ | (14.5) |  |  | $ | (0.2) |  |  | $ | (11.0) |  |  | $ | (0.2) |
Intercompany Income Allocations | N/A |  | $ | (0.6) |  |  | $ | (0.4) |  |  | $ | (0.1) |  |  | N/A |  | $ | (0.4) |  |  | $ | (0.5) |  |  | $ | (0.1) |

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| Pension and SERP |  | PBOP
| For the Six Months Ended June 30, 2023 |  | For the Six Months Ended June 30, 2023
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Service Cost | $ | 21.7 |  |  | $ | 6.1 |  |  | $ | 4.0 |  |  | $ | 2.2 |  |  | $ | 3.8 |  |  | $ | 0.6 |  |  | $ | 0.6 |  |  | $ | 0.4 |
Interest Cost | 127.2 |  |  | 25.3 |  |  | 27.0 |  |  | 13.6 |  |  | 16.9 |  |  | 3.1 |  |  | 4.6 |  |  | 1.8 |
Expected Return on Plan Assets | (232.4) |  |  | (47.1) |  |  | (56.9) |  |  | (24.8) |  |  | (38.6) |  |  | (4.7) |  |  | (18.5) |  |  | (2.8) |
Actuarial Loss | 24.1 |  |  | 1.4 |  |  | 8.9 |  |  | 0.8 |  |  | — |  |  | — |  |  | — |  |  | — |
Prior Service Cost/(Credit) | 0.6 |  |  | — |  |  | 0.2 |  |  | — |  |  | (10.8) |  |  | 0.6 |  |  | (8.5) |  |  | 0.2 |
Settlement Loss | 3.7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Total Net Periodic Benefit Plan Income | $ | (55.1) |  |  | $ | (14.3) |  |  | $ | (16.8) |  |  | $ | (8.2) |  |  | $ | (28.7) |  |  | $ | (0.4) |  |  | $ | (21.8) |  |  | $ | (0.4) |
Intercompany Income Allocations | N/A |  | $ | (2.6) |  |  | $ | (2.1) |  |  | $ | (0.6) |  |  | N/A |  | $ | (0.9) |  |  | $ | (1.1) |  |  | $ | (0.3) |

9. COMMITMENTS AND CONTINGENCIES
A. Environmental Matters
Eversource, CL&P, NSTAR Electric and PSNH are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites. Eversource, CL&P, NSTAR Electric and PSNH have an active environmental auditing and training program and each believes it is substantially in compliance with all enacted laws and regulations.
The number of environmental sites and related reserves for which remediation or long-term monitoring, preliminary site work or site assessment is being performed are as follows:

| As of June 30, 2024 |  | As of December 31, 2023
| Number of Sites |  | Reserve (in millions) |  | Number of Sites |  | Reserve (in millions)
Eversource | 66 |  |  | $ | 127.1 |  |  | 65 |  |  | $ | 128.2 |
CL&P | 16 |  |  | 13.4 |  |  | 16 |  |  | 13.8 |
NSTAR Electric | 13 |  |  | 5.9 |  |  | 12 |  |  | 5.4 |
PSNH | 8 |  |  | 6.5 |  |  | 8 |  |  | 7.6 |

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. Eversource’s reserve balances related to these former MGP sites were $115.5 million and $117.1 million as of June 30, 2024 and December 31, 2023, 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 2023 Form 10-K.
Renewable Energy: Renewable energy contracts include non-cancelable commitments under contracts of CL&P for the purchase of energy and capacity from renewable energy facilities. The table now includes the long-term commitments of CL&P pertaining to renewable energy purchase contracts that have now commenced significant construction activities.

CL&P |  |  |  |  |  |  |  |  |  |  |  |  |
(Millions of Dollars) | 2024 |  | 2025 |  | 2026 |  | 2027 |  | 2028 |  | Thereafter |  | Total
Renewable Energy | $ | 338.1 |  |  | $ | 651.3 |  |  | $ | 728.7 |  |  | $ | 732.3 |  |  | $ | 734.5 |  |  | $ | 3,798.2 |  |  | $ | 6,983.1 |

Additionally, Renewable Energy contract costs within long-term contractual arrangements at PSNH as of December 31, 2023 included renewable energy purchase contracts related to the purchase of capacity, energy and RECs from a New Hampshire generation plant totaling $503.2 million. The NHPUC approved the termination of the PPA related to this generation plant effective February 29, 2024. As of June 30, 2024, there are no remaining long-term renewable energy purchase contracts at PSNH.
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C. Guarantees and Indemnifications
In the normal course of business, Eversource parent provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric and PSNH, in the form of guarantees. 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. The fair value of guarantees issued on behalf of unconsolidated entities are recorded within Other Long-Term Liabilities on the balance sheet, and were $1.9 million and $4.4 million as of June 30, 2024 and December 31, 2023, respectively. Eversource regularly reviews performance risk under these guarantee arrangements, and believes the likelihood of payments being required under the guarantees is remote. 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 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, 2024
Company (Obligor) |  | Description |  | Maximum Exposure (in millions)
North East Offshore, LLC, Sunrise Wind LLC, Revolution Wind, LLC and South Fork Wind, LLC |  | Offshore wind construction-related purchase agreements with third-party contractors (1) (7) |  | $ | 1,418.1 |
Eversource Investment LLC and South Fork Class B Member, LLC |  | Funding and indemnification obligations of South Fork Wind and North East Offshore, LLC (2) |  | 333.9 |
Eversource Investment LLC |  | Letters of Credit (3) (7) |  | 23.2 |
Eversource TEI LLC |  | South Fork Wind Tax Equity (4) |  | 50.0 |
South Fork Wind, LLC |  | Power Purchase Agreement Security (5) |  | 7.1 |
Various Eversource subsidiaries |  | Surety bonds (6) |  | 35.1 |

(1) Eversource parent issued guarantees on behalf of its 50 percent-owned affiliates, North East Offshore, LLC (NEO), Sunrise Wind LLC, Revolution Wind, LLC and South Fork Wind, LLC, under which Eversource parent agreed to guarantee each entity’s performance of obligations under certain construction-related purchase agreements with third-party contractors, in an aggregate amount not to exceed $2.83 billion. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging between October 2024 and October 2028 and (ii) full performance of the guaranteed obligations. 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.
(2) Eversource parent issued guarantees on behalf of its wholly-owned subsidiary Eversource Investment LLC (EI), which holds Eversource's investments in offshore wind-related equity method investments, and on behalf of its 50 percent-owned affiliate, South Fork Class B Member, LLC, whereby Eversource parent will guarantee each entity’s performance of certain capital expenditure funding obligations during the construction phases of the South Fork Wind project and NEO’s underlying offshore wind projects. Eversource parent also guaranteed certain indemnification obligations of EI associated with third party credit support for EI’s investment in NEO. These guarantees will not exceed $1.52 billion and expire upon the full performance of the guaranteed obligations.
(3) Eversource parent entered into a guarantee on behalf of EI, 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. As of June 30, 2024, EI has issued letters of credit on behalf of South Fork Wind, LLC, Sunrise Wind LLC and Revolution Wind, LLC totaling $23.2 million. The guarantee will remain in effect until full performance of the guaranteed obligations.
(4) Eversource parent issued a guarantee on behalf of its wholly-owned subsidiary, Eversource TEI LLC, whereby Eversource parent will guarantee Eversource TEI LLC’s performance of certain obligations, in an amount not to exceed $50.0 million, in connection with any remaining obligations under the LLC agreement. Eversource parent’s obligations expire upon the full performance of the guaranteed obligations.
(5) Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, South Fork Wind, LLC, whereby Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations, in an amount not to exceed $7.1 million, under a Power Purchase Agreement between the Long Island Power Authority and South Fork Wind, LLC (the Agreement). The guarantee expires upon the later of (i) the end of the Agreement term and (ii) full performance of the guaranteed obligations.
(6) Surety bonds expire in 2024 and 2025. 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.
(7) On July 9, 2024, Eversource completed the sale to Ørsted of its 50 percent ownership interest in Sunrise Wind. In connection with the sale, (i) existing Eversource parent guarantees on behalf of Sunrise Wind of obligations under certain construction-related purchase agreements with third-party contractors with a maximum exposure of $557.2 million, and (ii) $17.8 million of letters of credit under a letter of credit facility with a financial institution on behalf of Sunrise Wind, all reflected in the table above as of June 30, 2024, were terminated.
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In addition, an existing guarantee agreement on behalf of NEO, that also included Sunrise Wind, with a maximum exposure of $1.2 billion ($598.6 million of which is reflected in the above table as of June 30, 2024) was terminated. Concurrent with the termination of that guarantee agreement, Eversource parent entered into a new guarantee agreement on behalf of TurbineCo, LLC (successor in interest to NEO), that also includes Sunrise Wind, with a maximum exposure of $523.8 million. However, Ørsted has agreed to indemnify Eversource parent for all claims under that new guarantee agreement related to the performance of Sunrise Wind.
D. Spent Nuclear Fuel Obligations - Yankee Companies
CL&P, NSTAR Electric and PSNH have plant closure and fuel storage cost obligations to the Yankee Companies, which have each completed the physical decommissioning of their respective nuclear power facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies fund these costs through litigation proceeds received from the DOE and, to the extent necessary, through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. CL&P, NSTAR Electric and PSNH, in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies collect amounts that management believes are adequate to recover the remaining plant closure and fuel storage cost estimates for the respective plants. Management believes CL&P and NSTAR Electric will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers.
Spent Nuclear Fuel Litigation:
The Yankee Companies have filed complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to accept delivery of, and provide for a permanent facility to store, spent nuclear fuel pursuant to the terms of the 1983 spent fuel and high-level waste disposal contracts between the Yankee Companies and the DOE. The court previously awarded the Yankee Companies damages for Phases I, II, III and IV of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2016, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.
DOE Phase V Damages - On March 25, 2021, each of the Yankee Companies filed a fifth set of lawsuits against the DOE in the Court of Federal Claims resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2017 to 2020. The Yankee Companies filed claims seeking monetary damages totaling $120.4 million for CYAPC, YAEC and MYAPC. Pursuant to a June 2, 2022 court order, the Yankee Companies were subsequently permitted to include monetary damages relating to the year 2021 in the DOE Phase V complaint. The Yankee Companies submitted a supplemental filing to include these costs of $33.1 million on June 8, 2022. In June 2024, the court set dates for the DOE Phase V trial of October 28, 2024 through November 8, 2024.
E. FERC ROE Complaints
Four separate complaints were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively, the Complainants). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive (incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.
The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, FERC issued Opinion No. 531-A and set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the Court).
All amounts associated with the first complaint period have been refunded, which totaled $38.9 million (pre-tax and excluding interest) at Eversource and reflected both the base ROE and incentive cap prescribed by the FERC order. The refund consisted of $22.4 million for CL&P, $13.7 million for NSTAR Electric and $2.8 million for PSNH.
Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of both June 30, 2024 and December 31, 2023. 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, 2024 and December 31, 2023.
On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.
The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.
If the results of the illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order.
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On November 21, 2019, FERC issued Opinion No. 569 affecting the two pending transmission ROE complaints against the Midcontinent ISO (MISO) transmission owners, in which FERC adopted a new methodology for determining base ROEs. Various parties sought rehearing. On December 23, 2019, the NETOs filed supplementary materials in the NETOs' four pending cases to respond to this new methodology because of the uncertainty of the applicability to the NETOs' cases. On May 21, 2020, the FERC issued its order in Opinion No. 569-A on the rehearing of the MISO transmission owners' cases, in which FERC again changed its methodology for determining the MISO transmission owners' base ROEs. On November 19, 2020, the FERC issued Opinion No. 569-B denying rehearing of Opinion No. 569-A and reaffirmed the methodology previously adopted in Opinion No. 569-A. The new methodology differs significantly from the methodology proposed by FERC in its October 16, 2018 order to determine the NETOs' base ROEs in its four pending cases. FERC Opinion Nos. 569-A and 569-B were appealed to the Court. On August 9, 2022, the Court issued its decision vacating MISO ROE FERC Opinion Nos. 569, 569-A and 569-B and remanded to FERC to reopen the proceedings. The Court found that FERC’s development of the new return methodology was arbitrary and capricious due to FERC’s failure to offer a reasonable explanation for its decision to reintroduce the risk-premium financial model in its new methodology for calculating a just and reasonable return. At this time, Eversource cannot predict how and when FERC will address the Court’s findings on the remand of the MISO FERC opinions or any potential associated impact on the NETOs’ four pending ROE complaint cases.
Given the significant uncertainty regarding the applicability of the FERC opinions in the MISO transmission owners’ two complaint cases to the NETOs’ pending four complaint cases, Eversource concluded that there is no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods at this time. As well, Eversource cannot reasonably estimate a range of loss for any of the four complaint proceedings at this time.
Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.
A change of 10 basis points to the base ROE used to establish the reserves would impact Eversource’s after-tax earnings by an average of approximately $3 million for each of the four 15-month complaint periods.
10. FAIR VALUE OF FINANCIAL INSTRUMENTS
The following methods and assumptions were used to estimate the fair value of each of the following financial instruments:
Preferred Stock, Long-Term Debt and Rate Reduction Bonds: The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections. The fair value of long-term debt and RRB debt securities is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields. The fair values provided in the table below are classified as Level 2 within the fair value hierarchy. Carrying amounts and estimated fair values are as follows:

| Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
(Millions of Dollars) | Carrying Amount |  | Fair Value |  | Carrying Amount |  | Fair Value |  | Carrying Amount |  | Fair Value |  | Carrying Amount |  | Fair Value
As of June 30, 2024: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Preferred Stock Not Subject to Mandatory Redemption | $ | 155.6 |  |  | $ | 121.8 |  |  | $ | 116.2 |  |  | $ | 89.6 |  |  | $ | 43.0 |  |  | $ | 32.2 |  |  | $ | — |  |  | $ | — |
Long-Term Debt | 27,164.3 |  |  | 25,027.7 |  |  | 4,954.1 |  |  | 4,537.7 |  |  | 5,093.0 |  |  | 4,723.9 |  |  | 1,731.5 |  |  | 1,527.2 |
Rate Reduction Bonds | 388.9 |  |  | 368.8 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 388.9 |  |  | 368.8 |
As of December 31, 2023: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Preferred Stock Not Subject to Mandatory Redemption | $ | 155.6 |  |  | $ | 122.2 |  |  | $ | 116.2 |  |  | $ | 90.4 |  |  | $ | 43.0 |  |  | $ | 31.8 |  |  | $ | — |  |  | $ | — |
Long-Term Debt | 24,413.5 |  |  | 22,855.2 |  |  | 4,814.4 |  |  | 4,572.0 |  |  | 4,496.9 |  |  | 4,273.7 |  |  | 1,431.6 |  |  | 1,292.6 |
Rate Reduction Bonds | 410.5 |  |  | 395.0 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 410.5 |  |  | 395.0 |

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.
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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, 2024 |  | For the Six Months Ended June 30, 2023
Eversource (Millions of Dollars) | Qualified Cash Flow Hedging Instruments |  | Defined Benefit Plans |  | Total |  | Qualified Cash Flow Hedging Instruments |  | Unrealized Gains/(Losses) on Marketable Securities |  | Defined Benefit Plans |  | Total
Balance as of Beginning of Period | $ | (0.4) |  |  | $ | (33.3) |  |  | $ | (33.7) |  |  | $ | (0.4) |  |  | $ | (1.2) |  |  | $ | (37.8) |  |  | $ | (39.4) |
OCI Before Reclassifications | — |  |  | (0.9) |  |  | (0.9) |  |  | — |  |  | — |  |  | 0.1 |  |  | 0.1 |
Amounts Reclassified from AOCI | — |  |  | 5.0 |  |  | 5.0 |  |  | — |  |  | 1.2 |  |  | 6.0 |  |  | 7.2 |
Net OCI | — |  |  | 4.1 |  |  | 4.1 |  |  | — |  |  | 1.2 |  |  | 6.1 |  |  | 7.3 |
Balance as of End of Period | $ | (0.4) |  |  | $ | (29.2) |  |  | $ | (29.6) |  |  | $ | (0.4) |  |  | $ | — |  |  | $ | (31.7) |  |  | $ | (32.1) |

Defined benefit plan OCI amounts before reclassifications relate to actuarial gains and losses that arose during the year and were recognized in AOCI. The unamortized actuarial gains and losses and prior service costs on the defined benefit plans are amortized from AOCI into Other Income, Net over the average future employee service period, and are reflected in amounts reclassified from AOCI.
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, 2024 and December 31, 2023 |  | Issued as of
| Par Value |  |  | June 30, 2024 |  | December 31, 2023
Eversource | $ | 5 |  |  | 410,000,000 |  |  | 364,190,722 |  |  | 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 |

Common Share Issuances and 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. In the first six months of 2024, Eversource issued 4,206,649 common shares, which resulted in proceeds of $248.2 million, net of issuance costs. Eversource used the net proceeds received for general corporate purposes. In 2023, no shares were issued under this agreement.
Treasury Shares: As of June 30, 2024 and December 31, 2023, there were 9,624,651 and 10,443,807 Eversource common shares held as treasury shares, respectively. As of June 30, 2024 and December 31, 2023, there we re 354,566,071 and 349,540,266 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. 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.
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, 2024 and 2023 and $3.8 million for each of the six months ended June 30, 2024 and 2023. 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, 2024 and December 31, 2023. 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, 2024 and 2023, there were no antidilutive share awards excluded from the computation of diluted EPS.
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The following table sets forth the components of basic and diluted EPS:

Eversource (Millions of Dollars, except share information) | For the Three Months Ended |  | For the Six Months Ended
June 30, 2024 |  | June 30, 2023 |  | June 30, 2024 |  | June 30, 2023
Net Income Attributable to Common Shareholders | $ | 335.3 |  |  | $ | 15.4 |  |  | $ | 857.2 |  |  | $ | 506.6 |
Weighted Average Common Shares Outstanding: |  |  |  |  |  |  |
Basic | 353,212,378 |  |  | 349,462,359 |  |  | 351,964,747 |  |  | 349,339,752 |
Dilutive Effect | 207,280 |  |  | 267,623 |  |  | 243,693 |  |  | 331,244 |
Diluted | 353,419,658 |  |  | 349,729,982 |  |  | 352,208,440 |  |  | 349,670,996 |
Basic EPS | $ | 0.95 |  |  | $ | 0.04 |  |  | $ | 2.44 |  |  | $ | 1.45 |
Diluted EPS | $ | 0.95 |  |  | $ | 0.04 |  |  | $ | 2.43 |  |  | $ | 1.45 |

15. REVENUES
The following tables present operating revenues disaggregated by revenue source:

| For the Three Months Ended June 30, 2024
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 1,027.5 |  |  | $ | 204.1 |  |  | $ | — |  |  | $ | 37.8 |  |  | $ | — |  |  | $ | — |  |  | $ | 1,269.4 |
Commercial | 683.2 |  |  | 116.4 |  |  | — |  |  | 18.2 |  |  | — |  |  | (1.5) |  |  | 816.3 |
Industrial | 89.9 |  |  | 35.6 |  |  | — |  |  | 1.1 |  |  | — |  |  | (6.0) |  |  | 120.6 |
Total Retail Tariff Sales Revenues | 1,800.6 |  |  | 356.1 |  |  | — |  |  | 57.1 |  |  | — |  |  | (7.5) |  |  | 2,206.3 |
Wholesale Transmission Revenues | — |  |  | — |  |  | 512.9 |  |  | — |  |  | — |  |  | (396.1) |  |  | 116.8 |
Wholesale Market Sales Revenues | 132.0 |  |  | 35.0 |  |  | — |  |  | 1.0 |  |  | — |  |  | — |  |  | 168.0 |
Other Revenues from Contracts with Customers | 16.1 |  |  | 1.5 |  |  | 3.6 |  |  | 1.5 |  |  | 395.2 |  |  | (393.7) |  |  | 24.2 |
Total Revenues from Contracts with Customers | 1,948.7 |  |  | 392.6 |  |  | 516.5 |  |  | 59.6 |  |  | 395.2 |  |  | (797.3) |  |  | 2,515.3 |
Alternative Revenue Programs | 14.0 |  |  | 0.2 |  |  | 17.5 |  |  | (2.4) |  |  | — |  |  | (15.8) |  |  | 13.5 |
Other Revenues | 3.6 |  |  | 0.7 |  |  | 0.1 |  |  | 0.3 |  |  | — |  |  | — |  |  | 4.7 |
Total Operating Revenues | $ | 1,966.3 |  |  | $ | 393.5 |  |  | $ | 534.1 |  |  | $ | 57.5 |  |  | $ | 395.2 |  |  | $ | (813.1) |  |  | $ | 2,533.5 |
| For the Six Months Ended June 30, 2024
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 | $ | 2,281.6 |  |  | $ | 711.7 |  |  | $ | — |  |  | $ | 68.0 |  |  | $ | — |  |  | $ | — |  |  | $ | 3,061.3 |
Commercial | 1,390.7 |  |  | 363.4 |  |  | — |  |  | 34.4 |  |  | — |  |  | (3.2) |  |  | 1,785.3 |
Industrial | 177.6 |  |  | 95.4 |  |  | — |  |  | 2.2 |  |  | — |  |  | (11.1) |  |  | 264.1 |
Total Retail Tariff Sales Revenues | 3,849.9 |  |  | 1,170.5 |  |  | — |  |  | 104.6 |  |  | — |  |  | (14.3) |  |  | 5,110.7 |
Wholesale Transmission Revenues | — |  |  | — |  |  | 987.0 |  |  | — |  |  | — |  |  | (757.7) |  |  | 229.3 |
Wholesale Market Sales Revenues | 297.3 |  |  | 93.3 |  |  | — |  |  | 1.9 |  |  | — |  |  | — |  |  | 392.5 |
Other Revenues from Contracts with Customers | 44.5 |  |  | 2.6 |  |  | 7.6 |  |  | 1.3 |  |  | 838.8 |  |  | (835.2) |  |  | 59.6 |
Total Revenues from Contracts with Customers | 4,191.7 |  |  | 1,266.4 |  |  | 994.6 |  |  | 107.8 |  |  | 838.8 |  |  | (1,607.2) |  |  | 5,792.1 |
Alternative Revenue Programs | 27.3 |  |  | 31.6 |  |  | 47.0 |  |  | (0.7) |  |  | — |  |  | (42.6) |  |  | 62.6 |
Other Revenues | 9.0 |  |  | 1.5 |  |  | 0.3 |  |  | 0.6 |  |  | — |  |  | — |  |  | 11.4 |
Total Operating Revenues | $ | 4,228.0 |  |  | $ | 1,299.5 |  |  | $ | 1,041.9 |  |  | $ | 107.7 |  |  | $ | 838.8 |  |  | $ | (1,649.8) |  |  | $ | 5,866.1 |

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| For the Three Months Ended June 30, 2023
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 1,142.2 |  |  | $ | 198.4 |  |  | $ | — |  |  | $ | 38.9 |  |  | $ | — |  |  | $ | — |  |  | $ | 1,379.5 |
Commercial | 692.1 |  |  | 129.9 |  |  | — |  |  | 18.2 |  |  | — |  |  | (1.2) |  |  | 839.0 |
Industrial | 84.9 |  |  | 41.9 |  |  | — |  |  | 1.1 |  |  | — |  |  | (4.7) |  |  | 123.2 |
Total Retail Tariff Sales Revenues | 1,919.2 |  |  | 370.2 |  |  | — |  |  | 58.2 |  |  | — |  |  | (5.9) |  |  | 2,341.7 |
Wholesale Transmission Revenues | — |  |  | — |  |  | 403.0 |  |  | — |  |  | — |  |  | (303.8) |  |  | 99.2 |
Wholesale Market Sales Revenues | 112.3 |  |  | 39.8 |  |  | — |  |  | 1.0 |  |  | — |  |  | — |  |  | 153.1 |
Other Revenues from Contracts with Customers | 21.0 |  |  | 1.1 |  |  | 4.5 |  |  | 2.0 |  |  | 408.8 |  |  | (405.8) |  |  | 31.6 |
Total Revenues from Contracts with Customers | 2,052.5 |  |  | 411.1 |  |  | 407.5 |  |  | 61.2 |  |  | 408.8 |  |  | (715.5) |  |  | 2,625.6 |
Alternative Revenue Programs | (3.0) |  |  | (3.1) |  |  | 72.5 |  |  | (3.4) |  |  | — |  |  | (65.7) |  |  | (2.7) |
Other Revenues | 4.9 |  |  | 1.1 |  |  | 0.1 |  |  | 0.3 |  |  | — |  |  | — |  |  | 6.4 |
Total Operating Revenues | $ | 2,054.4 |  |  | $ | 409.1 |  |  | $ | 480.1 |  |  | $ | 58.1 |  |  | $ | 408.8 |  |  | $ | (781.2) |  |  | $ | 2,629.3 |
| For the Six Months Ended June 30, 2023
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 2,606.2 |  |  | $ | 774.9 |  |  | $ | — |  |  | $ | 67.9 |  |  | $ | — |  |  | $ | — |  |  | $ | 3,449.0 |
Commercial | 1,480.5 |  |  | 450.0 |  |  | — |  |  | 33.7 |  |  | — |  |  | (2.3) |  |  | 1,961.9 |
Industrial | 174.1 |  |  | 111.4 |  |  | — |  |  | 2.1 |  |  | — |  |  | (9.7) |  |  | 277.9 |
Total Retail Tariff Sales Revenues | 4,260.8 |  |  | 1,336.3 |  |  | — |  |  | 103.7 |  |  | — |  |  | (12.0) |  |  | 5,688.8 |
Wholesale Transmission Revenues | — |  |  | — |  |  | 838.1 |  |  | — |  |  | — |  |  | (629.1) |  |  | 209.0 |
Wholesale Market Sales Revenues | 329.6 |  |  | 88.9 |  |  | — |  |  | 1.8 |  |  | — |  |  | — |  |  | 420.3 |
Other Revenues from Contracts with Customers | 39.2 |  |  | 2.7 |  |  | 9.1 |  |  | 4.0 |  |  | 822.7 |  |  | (818.3) |  |  | 59.4 |
Total Revenues from Contracts with Customers | 4,629.6 |  |  | 1,427.9 |  |  | 847.2 |  |  | 109.5 |  |  | 822.7 |  |  | (1,459.4) |  |  | 6,377.5 |
Alternative Revenue Programs | 3.1 |  |  | 24.3 |  |  | 91.2 |  |  | (1.7) |  |  | — |  |  | (82.7) |  |  | 34.2 |
Other Revenues | 10.3 |  |  | 2.1 |  |  | 0.4 |  |  | 0.5 |  |  | — |  |  | — |  |  | 13.3 |
Total Operating Revenues | $ | 4,643.0 |  |  | $ | 1,454.3 |  |  | $ | 938.8 |  |  | $ | 108.3 |  |  | $ | 822.7 |  |  | $ | (1,542.1) |  |  | $ | 6,425.0 |

| For the Three Months Ended June 30, 2024 |  | For the Three Months Ended June 30, 2023
(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH |  | CL&P |  | NSTAR Electric |  | PSNH
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 513.7 |  |  | $ | 380.2 |  |  | $ | 133.6 |  |  | $ | 593.7 |  |  | $ | 370.5 |  |  | $ | 178.0 |
Commercial | 248.0 |  |  | 354.4 |  |  | 81.1 |  |  | 255.0 |  |  | 347.2 |  |  | 90.2 |
Industrial | 32.6 |  |  | 30.2 |  |  | 27.1 |  |  | 31.3 |  |  | 31.1 |  |  | 22.5 |
Total Retail Tariff Sales Revenues | 794.3 |  |  | 764.8 |  |  | 241.8 |  |  | 880.0 |  |  | 748.8 |  |  | 290.7 |
Wholesale Transmission Revenues | 218.8 |  |  | 200.9 |  |  | 93.2 |  |  | 172.5 |  |  | 166.9 |  |  | 63.6 |
Wholesale Market Sales Revenues | 97.4 |  |  | 27.0 |  |  | 7.6 |  |  | 62.9 |  |  | 32.5 |  |  | 16.9 |
Other Revenues from Contracts with Customers | 1.5 |  |  | 13.3 |  |  | 5.5 |  |  | 8.8 |  |  | 12.9 |  |  | 4.4 |
Total Revenues from Contracts with Customers | 1,112.0 |  |  | 1,006.0 |  |  | 348.1 |  |  | 1,124.2 |  |  | 961.1 |  |  | 375.6 |
Alternative Revenue Programs | 23.9 |  |  | 4.2 |  |  | 3.4 |  |  | 52.6 |  |  | (5.0) |  |  | 21.9 |
Other Revenues | 1.5 |  |  | 1.6 |  |  | 0.6 |  |  | 2.5 |  |  | 1.8 |  |  | 0.7 |
Eliminations | (172.8) |  |  | (166.7) |  |  | (64.8) |  |  | (145.2) |  |  | (138.9) |  |  | (48.1) |
Total Operating Revenues | $ | 964.6 |  |  | $ | 845.1 |  |  | $ | 287.3 |  |  | $ | 1,034.1 |  |  | $ | 819.0 |  |  | $ | 350.1 |

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| For the Six Months Ended June 30, 2024 |  | For the Six Months Ended June 30, 2023
(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH |  | CL&P |  | NSTAR Electric |  | PSNH
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 1,140.6 |  |  | $ | 842.4 |  |  | $ | 298.6 |  |  | $ | 1,355.9 |  |  | $ | 838.3 |  |  | $ | 412.0 |
Commercial | 500.4 |  |  | 727.9 |  |  | 163.1 |  |  | 550.3 |  |  | 731.5 |  |  | 198.8 |
Industrial | 65.8 |  |  | 60.1 |  |  | 51.7 |  |  | 65.2 |  |  | 63.8 |  |  | 45.1 |
Total Retail Tariff Sales Revenues | 1,706.8 |  |  | 1,630.4 |  |  | 513.4 |  |  | 1,971.4 |  |  | 1,633.6 |  |  | 655.9 |
Wholesale Transmission Revenues | 419.5 |  |  | 389.7 |  |  | 177.8 |  |  | 368.3 |  |  | 334.7 |  |  | 135.1 |
Wholesale Market Sales Revenues | 218.6 |  |  | 58.6 |  |  | 20.1 |  |  | 217.6 |  |  | 73.6 |  |  | 38.4 |
Other Revenues from Contracts with Customers | 18.0 |  |  | 24.4 |  |  | 10.7 |  |  | 18.7 |  |  | 23.6 |  |  | 7.3 |
Total Revenues from Contracts with Customers | 2,362.9 |  |  | 2,103.1 |  |  | 722.0 |  |  | 2,576.0 |  |  | 2,065.5 |  |  | 836.7 |
Alternative Revenue Programs | 51.3 |  |  | 12.0 |  |  | 11.0 |  |  | 77.3 |  |  | (14.5) |  |  | 31.5 |
Other Revenues | 4.3 |  |  | 3.6 |  |  | 1.4 |  |  | 4.7 |  |  | 4.3 |  |  | 1.7 |
Eliminations | (332.6) |  |  | (326.0) |  |  | (121.0) |  |  | (284.9) |  |  | (280.0) |  |  | (99.7) |
Total Operating Revenues | $ | 2,085.9 |  |  | $ | 1,792.7 |  |  | $ | 613.4 |  |  | $ | 2,373.1 |  |  | $ | 1,775.3 |  |  | $ | 770.2 |

16. SEGMENT INFORMATION
Eversource is organized into the Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reportable segments and Other based on a combination of factors, including the characteristics of each segments' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates. These reportable segments represent substantially all of Eversource's total consolidated revenues. Revenues from the sale of electricity, natural gas and water primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer. The Electric Distribution reportable segment includes the results of NSTAR Electric's solar power facilities. Eversource's reportable segments are determined based upon the level at which Eversource's chief operating decision maker assesses performance and makes decisions about the allocation of company resources.
The remainder of Eversource's operations is presented as Other in the tables below and primarily consists of 1) the equity in earnings of Eversource parent from its subsidiaries and intercompany interest income, both of which are eliminated in consolidation, and interest expense related to the debt of Eversource parent, 2) the revenues and expenses of Eversource Service, most of which are eliminated in consolidation, 3) the operations of CYAPC and YAEC, 4) the results of other unregulated subsidiaries, which are not part of its core business, and 5) Eversource parent's equity ownership interests that are not consolidated, which primarily include the offshore wind business, a natural gas pipeline owned by Enbridge, Inc., and a renewable energy investment fund that was liquidated in the first quarter of 2023.
In the ordinary course of business, Yankee Gas, NSTAR Gas and EGMA purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline project described above. These affiliate transaction costs total $77.7 million annually and are classified as Purchased Power, Purchased Natural Gas and Transmission on the Eversource statements of income.
Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has one reportable segment.
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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, 2024
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Operating Revenues | $ | 1,966.3 |  |  | $ | 393.5 |  |  | $ | 534.1 |  |  | $ | 57.5 |  |  | $ | 395.2 |  |  | $ | (813.1) |  |  | $ | 2,533.5 |
Depreciation and Amortization | (34.9) |  |  | (50.1) |  |  | (98.8) |  |  | (10.8) |  |  | (48.5) |  |  | 2.7 |  |  | (240.4) |
Other Operating Expenses | (1,713.6) |  |  | (295.2) |  |  | (147.1) |  |  | (30.9) |  |  | (314.2) |  |  | 810.4 |  |  | (1,690.6) |
Operating Income | $ | 217.8 |  |  | $ | 48.2 |  |  | $ | 288.2 |  |  | $ | 15.8 |  |  | $ | 32.5 |  |  | $ | — |  |  | $ | 602.5 |
Interest Expense | $ | (90.9) |  |  | $ | (22.3) |  |  | $ | (46.0) |  |  | $ | (9.7) |  |  | $ | (161.0) |  |  | $ | 58.6 |  |  | $ | (271.3) |
Other Income, Net | 67.0 |  |  | 10.9 |  |  | 12.2 |  |  | 0.6 |  |  | 473.5 |  |  | (448.9) |  |  | 115.3 |
Net Income Attributable to Common Shareholders | 149.7 |  |  | 27.1 |  |  | 189.0 |  |  | 8.0 |  |  | 351.8 |  |  | (390.3) |  |  | 335.3 |
| For the Six Months Ended June 30, 2024
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Operating Revenues | $ | 4,228.0 |  |  | $ | 1,299.5 |  |  | $ | 1,041.9 |  |  | $ | 107.7 |  |  | $ | 838.8 |  |  | $ | (1,649.8) |  |  | $ | 5,866.1 |
Depreciation and Amortization | (144.6) |  |  | (133.2) |  |  | (199.8) |  |  | (11.5) |  |  | (94.1) |  |  | 5.2 |  |  | (578.0) |
Other Operating Expenses | (3,618.7) |  |  | (849.8) |  |  | (289.0) |  |  | (63.0) |  |  | (663.7) |  |  | 1,644.6 |  |  | (3,839.6) |
Operating Income | $ | 464.7 |  |  | $ | 316.5 |  |  | $ | 553.1 |  |  | $ | 33.2 |  |  | $ | 81.0 |  |  | $ | — |  |  | $ | 1,448.5 |
Interest Expense | $ | (173.4) |  |  | $ | (46.8) |  |  | $ | (86.9) |  |  | $ | (21.1) |  |  | $ | (307.2) |  |  | $ | 113.3 |  |  | $ | (522.1) |
Other Income, Net | 123.5 |  |  | 21.0 |  |  | 26.3 |  |  | 2.3 |  |  | 1,096.2 |  |  | (1,063.0) |  |  | 206.3 |
Net Income Attributable to Common Shareholders | 317.9 |  |  | 217.6 |  |  | 365.7 |  |  | 13.4 |  |  | 892.3 |  |  | (949.7) |  |  | 857.2 |
Cash Flows Used for Investments in Plant | 883.6 |  |  | 467.9 |  |  | 668.1 |  |  | 75.7 |  |  | 125.6 |  |  | — |  |  | 2,220.9 |

| For the Three Months Ended June 30, 2023
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Operating Revenues | $ | 2,054.4 |  |  | $ | 409.1 |  |  | $ | 480.1 |  |  | $ | 58.1 |  |  | $ | 408.8 |  |  | $ | (781.2) |  |  | $ | 2,629.3 |
Depreciation and Amortization | 82.1 |  |  | (41.7) |  |  | (92.0) |  |  | (14.1) |  |  | (38.0) |  |  | 2.2 |  |  | (101.5) |
Other Operating Expenses | (1,905.2) |  |  | (339.4) |  |  | (136.2) |  |  | (28.6) |  |  | (337.2) |  |  | 779.5 |  |  | (1,967.1) |
Operating Income | $ | 231.3 |  |  | $ | 28.0 |  |  | $ | 251.9 |  |  | $ | 15.4 |  |  | $ | 33.6 |  |  | $ | 0.5 |  |  | $ | 560.7 |
Interest Expense | $ | (68.2) |  |  | $ | (21.5) |  |  | $ | (42.2) |  |  | $ | (9.2) |  |  | $ | (100.6) |  |  | $ | 34.4 |  |  | $ | (207.3) |
Impairment of Offshore Wind Investment | — |  |  | — |  |  | — |  |  | — |  |  | (401.0) |  |  | — |  |  | (401.0) |
Other Income, Net | 47.9 |  |  | 9.7 |  |  | 9.5 |  |  | 1.5 |  |  | 100.9 |  |  | (74.6) |  |  | 94.9 |
Net Income Attributable to Common Shareholders | 165.5 |  |  | 11.7 |  |  | 161.0 |  |  | 9.3 |  |  | (292.4) |  |  | (39.7) |  |  | 15.4 |
| For the Six Months Ended June 30, 2023
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Operating Revenues | $ | 4,643.0 |  |  | $ | 1,454.3 |  |  | $ | 938.8 |  |  | $ | 108.3 |  |  | $ | 822.7 |  |  | $ | (1,542.1) |  |  | $ | 6,425.0 |
Depreciation and Amortization | 60.0 |  |  | (118.7) |  |  | (181.9) |  |  | (27.4) |  |  | (74.8) |  |  | 4.3 |  |  | (338.5) |
Other Operating Expenses | (4,247.4) |  |  | (1,069.8) |  |  | (264.5) |  |  | (56.5) |  |  | (676.9) |  |  | 1,538.8 |  |  | (4,776.3) |
Operating Income | $ | 455.6 |  |  | $ | 265.8 |  |  | $ | 492.4 |  |  | $ | 24.4 |  |  | $ | 71.0 |  |  | $ | 1.0 |  |  | $ | 1,310.2 |
Interest Expense | $ | (137.6) |  |  | $ | (42.7) |  |  | $ | (83.7) |  |  | $ | (18.6) |  |  | $ | (185.7) |  |  | $ | 66.4 |  |  | $ | (401.9) |
Impairment of Offshore Wind Investment | — |  |  | — |  |  | — |  |  | — |  |  | (401.0) |  |  | — |  |  | (401.0) |
Other Income, Net | 102.1 |  |  | 18.7 |  |  | 18.9 |  |  | 2.7 |  |  | 666.8 |  |  | (625.3) |  |  | 183.9 |
Net Income Attributable to Common Shareholders | 331.0 |  |  | 181.9 |  |  | 316.1 |  |  | 10.8 |  |  | 224.7 |  |  | (557.9) |  |  | 506.6 |
Cash Flows Used for Investments in Plant | 817.3 |  |  | 371.5 |  |  | 636.9 |  |  | 74.7 |  |  | 139.1 |  |  | — |  |  | 2,039.5 |

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, 2024 | $ | 30,943.9 |  |  | $ | 9,036.6 |  |  | $ | 15,417.3 |  |  | $ | 3,018.6 |  |  | $ | 28,662.1 |  |  | $ | (28,726.0) |  |  | $ | 58,352.5 |
As of December 31, 2023 | 29,426.4 |  |  | 8,775.3 |  |  | 14,806.5 |  |  | 2,944.8 |  |  | 26,337.7 |  |  | (26,678.5) |  |  | 55,612.2 |

38

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, 2024, as well as the Eversource 2023 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. Our earnings discussion includes financial measures that are not recognized under GAAP (non-GAAP) referencing our earnings and EPS excluding the impairment charge for the offshore wind investments, a loss on the disposition of land that was initially acquired to construct the Northern Pass Transmission project and was subsequently abandoned, and certain transaction and transition costs. EPS by business is also a non-GAAP financial measure 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. The earnings and EPS of each business do not represent a direct legal interest in the assets and liabilities of such business, but rather represent a direct interest in our assets and liabilities as a whole.
We use these non-GAAP financial measures to evaluate and provide details of earnings results by business and to more fully compare and explain our results without including these items. This information is among the primary indicators we use as a basis for evaluating performance and planning and forecasting of future periods. We believe the impacts of the impairment charge for the offshore wind investments, the loss on the disposition of land associated with an abandoned project, and transaction and transition costs are not indicative of our ongoing costs and performance. We view these charges as not directly related to the ongoing operations of the business and therefore not an indicator of baseline operating performance. Due to the nature and significance of the effect of these items on Net Income Attributable to Common Shareholders and EPS, we believe that the non-GAAP presentation is a more meaningful representation of our financial performance and provides additional and useful information to readers of this report in analyzing historical and future performance of our business. These non-GAAP financial measures should not be considered as alternatives to reported Net Income Attributable to Common Shareholders or EPS determined in accordance with GAAP as indicators of operating performance.
We make statements concerning our expectations, beliefs, plans, objectives, goals, strategies, assumptions of future events, future financial performance or growth and other statements that are not historical facts. These statements are "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. You can generally identify our forward-looking statements through the use of words or phrases such as "estimate," "expect," "anticipate," "intend," "plan," "project," "believe," "forecast," "should," "could," and other similar expressions. Forward-looking statements involve risks and uncertainties that may cause actual results or outcomes to differ materially from those included in our forward-looking statements. Forward-looking statements are based on the current expectations, estimates, assumptions or projections of management and are not guarantees of future performance. These expectations, estimates, assumptions or projections may vary materially from actual results. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, the following important factors that may cause our actual results or outcomes to differ materially from those contained in our forward-looking statements, including, but not limited to:
•cyberattacks or breaches, including those resulting in the compromise of the confidentiality of our proprietary information and the personal information of our customers,
•our ability to complete the sale of our offshore wind investments in the South Fork Wind and Revolution Wind projects on the timeline, terms and pricing we expect; if we and the counterparty are unable to satisfy all closing conditions and consummate the purchase and sale transaction with respect to these offshore wind assets; if we are unable to qualify for investment tax credits related to these projects; if we experience variability in the projected construction costs of these offshore wind projects, if there is a deterioration of market conditions in the offshore wind industry; and if the projects do not commence operation as scheduled or within budget or are not completed,
•disruptions in the capital markets or other events that make our access to necessary capital more difficult or costly,
• changes in economic conditions, including impact on interest rates, tax policies, and customer demand and payment ability,
• ability or inability to commence and complete our major strategic development projects and opportunities,
• acts of war or terrorism, physical attacks or grid disturbances that may damage and disrupt our electric transmission and electric, natural gas, and water distribution systems,
• actions or inaction of local, state and federal regulatory, public policy and taxing bodies,
• substandard performance of third-party suppliers and service providers,
• fluctuations in weather patterns, including extreme weather due to climate change,
• changes in business conditions, which could include disruptive technology or development of alternative energy sources related to our current or future business model,
• contamination of, or disruption in, our water supplies,
• changes in levels or timing of capital expenditures,
• changes in laws, regulations or regulatory policy, including compliance with environmental laws and regulations,
• changes in accounting standards and financial reporting regulations,
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• 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 2023 combined Annual Report on Form 10-K. This combined Quarterly Report on Form 10-Q and Eversource's 2023 combined Annual Report on Form 10-K also describe material contingencies and critical accounting policies in the accompanying Management's Discussion and Analysis of Financial Condition and Results of Operations and Combined Notes to Financial Statements. We encourage you to review these items.
Financial Condition and Business Analysis
Executive Summary
Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business. Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), Yankee Gas, NSTAR Gas and EGMA (natural gas utilities) and Aquarion (water utilities). Eversource is organized into the electric distribution, electric transmission, natural gas distribution, and water distribution reportable segments.
The following items in this executive summary are explained in more detail in this combined Quarterly Report on Form 10-Q:
Earnings Overview and Future Outlook:
•We earned $335.3 million, or $0.95 per share, in the second quarter of 2024, compared with $15.4 million, or $0.04 per share, in the second quarter of 2023. We earned $857.2 million, or $2.43 per share, in the first half of 2024, compared with $506.6 million, or $1.45 per share, in the first half of 2023. Our results for the second quarter and first half of 2023 include an after-tax impairment charge of $331.0 million, or $0.95 per share, recorded within Eversource Parent and Other Companies to reflect our estimate of the fair value of the offshore wind projects. Our 2023 results also include after-tax land abandonment and other charges recorded within Eversource Parent and Other Companies of $6.2 million, or $0.01 per share, in the second quarter of 2023 and $6.7 million, or $0.01 per share, in the first half of 2023. Excluding the offshore wind impairment and these other charges, our 2023 non-GAAP earnings were $352.6 million, or $1.00 per share, in the second quarter of 2023 and $844.3 million, or $2.41 per share, in the first half of 2023.
•We reaffirmed our projection to earn within a 2024 non-GAAP earnings guidance range of between $4.50 per share and $4.67 per share, which excludes the impact of the sales of our 50 percent interests in the three jointly-owned offshore wind projects and related transaction costs. We also reaffirmed our projection of our long-term EPS growth rate through 2028 within a 5 to 7 percent range.
Liquidity:
•Cash flows provided by operating activities totaled $962.0 million in the first half of 2024, compared with $647.3 million in the first half of 2023. Investments in property, plant and equipment totaled $2.22 billion in the first half of 2024, compared with $2.04 billion in the first half of 2023.
•Cash totaled $33.4 million as of June 30, 2024, compared with $53.9 million as of December 31, 2023. Our available borrowing capacity under our commercial paper programs totaled $1.21 billion as of June 30, 2024.
•In the first half of 2024, we issued $3.85 billion of new long-term debt and we repaid $900 million of long-term debt.
•On February 13, 2024, we initiated an exploratory assessment of a potential sale of our water distribution business.
•On May 1, 2024, our Board of Trustees approved a common share dividend payment of $0.715 per share, paid on June 28, 2024 to shareholders of record as of May 16, 2024.
Strategic Developments:
•On April 18, 2024, Eversource and Ørsted executed the equity and asset purchase agreement to sell Eversource’s 50 percent interest in Sunrise Wind to Ørsted for a gross purchase price of $230 million. The purchase price was subject to reduction for actual capital spending less than forecasted spending between signing the agreement in January and closing of the transaction. On July 9, 2024, Eversource completed the sale of its 50 percent ownership share of Sunrise Wind to Ørsted. In accordance with the equity and asset purchase agreement and after adjustment for the reduction in capital spending compared to forecasted, Ørsted paid Eversource $118 million at the closing of the
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sale transaction, and the remaining proceeds of $34 million will be paid after onshore construction is completed and certain other construction milestones are achieved.
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,
| 2024 |  | 2023 |  | 2024 |  | 2023
(Millions of Dollars, Except Per Share Amounts) | Amount |  | Per Share |  | Amount |  | Per Share |  | Amount |  | Per Share |  | Amount |  | Per Share
Net Income Attributable to Common Shareholders (GAAP) | $ | 335.3 |  |  | $ | 0.95 |  |  | $ | 15.4 |  |  | $ | 0.04 |  |  | $ | 857.2 |  |  | $ | 2.43 |  |  | $ | 506.6 |  |  | $ | 1.45 |
Regulated Companies | $ | 373.8 |  |  | $ | 1.06 |  |  | $ | 347.5 |  |  | $ | 0.99 |  |  | $ | 914.6 |  |  | $ | 2.59 |  |  | $ | 839.8 |  |  | $ | 2.40 |
Eversource Parent and Other Companies (Non-GAAP) | (38.5) |  |  | (0.11) |  |  | 5.1 |  |  | 0.01 |  |  | (57.4) |  |  | (0.16) |  |  | 4.5 |  |  | 0.01 |
Non-GAAP Earnings | $ | 335.3 |  |  | $ | 0.95 |  |  | $ | 352.6 |  |  | $ | 1.00 |  |  | $ | 857.2 |  |  | $ | 2.43 |  |  | $ | 844.3 |  |  | $ | 2.41 |
Impairment of Offshore Wind Investment (after-tax) (1) | — |  |  | — |  |  | (331.0) |  |  | (0.95) |  |  | — |  |  | — |  |  | (331.0) |  |  | (0.95) |
Land Abandonment Loss and Other Charges (after-tax) (2) | — |  |  | — |  |  | (6.2) |  |  | (0.01) |  |  | — |  |  | — |  |  | (6.7) |  |  | (0.01) |
Net Income Attributable to Common Shareholders (GAAP) | $ | 335.3 |  |  | $ | 0.95 |  |  | $ | 15.4 |  |  | $ | 0.04 |  |  | $ | 857.2 |  |  | $ | 2.43 |  |  | $ | 506.6 |  |  | $ | 1.45 |

(1) In the second quarter of 2023, we recorded an impairment charge resulting from the expected sales of our offshore wind investments and to reflect the estimate of the fair value of the offshore wind projects at that time. For further information, see "Business Development and Capital Expenditures – Offshore Wind Business" included in this Management's Discussion and Analysis of Financial Condition and Results of Operations.
(2) The 2023 charges primarily include a loss on the disposition of land. The land was initially acquired to construct the Northern Pass Transmission project and was subsequently abandoned.
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,
| 2024 |  | 2023 |  | 2024 |  | 2023
(Millions of Dollars, Except Per Share Amounts) | Amount |  | Per Share |  | Amount |  | Per Share |  | Amount |  | Per Share |  | Amount |  | Per Share
Electric Distribution | $ | 149.7 |  |  | $ | 0.42 |  |  | $ | 165.5 |  |  | $ | 0.47 |  |  | $ | 317.9 |  |  | $ | 0.90 |  |  | $ | 331.0 |  |  | $ | 0.95 |
Electric Transmission | 189.0 |  |  | 0.54 |  |  | 161.0 |  |  | 0.46 |  |  | 365.7 |  |  | 1.04 |  |  | 316.1 |  |  | 0.90 |
Natural Gas Distribution | 27.1 |  |  | 0.08 |  |  | 11.7 |  |  | 0.03 |  |  | 217.6 |  |  | 0.61 |  |  | 181.9 |  |  | 0.52 |
Water Distribution | 8.0 |  |  | 0.02 |  |  | 9.3 |  |  | 0.03 |  |  | 13.4 |  |  | 0.04 |  |  | 10.8 |  |  | 0.03 |
Net Income - Regulated Companies | $ | 373.8 |  |  | $ | 1.06 |  |  | $ | 347.5 |  |  | $ | 0.99 |  |  | $ | 914.6 |  |  | $ | 2.59 |  |  | $ | 839.8 |  |  | $ | 2.40 |

Our electric distribution segment earnings decreased $15.8 million and $13.1 million in the second quarter and the first half of 2024, respectively, as compared to the second quarter and the first half of 2023, due primarily to higher operations and maintenance expense driven by higher storm restoration costs, the absence of a prior year benefit at PSNH related to the establishment of a new regulatory tracking mechanism that allowed for the recovery of previously incurred operating expenses associated with poles acquired on May 1, 2023, higher interest expense, higher depreciation expense, and higher property tax expense. Those earnings decreases were partially offset by higher revenues from a base distribution rate increase at NSTAR Electric effective January 1, 2024 and from CL&P's capital tracking mechanism due to increased electric system improvements, and an increase in interest income primarily on regulatory deferrals.
Our electric transmission segment earnings increased $28.0 million and $49.6 million in the second quarter and the first half of 2024, respectively, as compared to the second quarter and the first half of 2023, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure, the impact of the annual billing and cost reconciliation filing with FERC, and higher AFUDC equity income.
Our natural gas distribution segment earnings increased $15.4 million and $35.7 million in the second quarter and the first half of 2024, respectively, as compared to the second quarter and the first half of 2023, due primarily to higher revenues from capital tracking mechanisms due to continued investments in natural gas infrastructure and a base distribution rate increase effective November 1, 2023 at NSTAR Gas, and lower operations and maintenance expense. Those earnings increases were partially offset by higher depreciation expense and higher interest expense.
Our water distribution segment earnings decreased $1.3 million in the second quarter of 2024, as compared to the second quarter of 2023, due primarily to higher operations and maintenance expense, higher interest expense, and higher depreciation expense.
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Our water distribution segment earnings increased $2.6 million in the first half of 2024, as compared to the first half of 2023, due primarily to an after-tax benefit of $6.3 million recorded to recognize the impacts of the Aquarion Water Company of Connecticut’s rate case decision from PURA from the effective date of the order on March 15, 2023 through June 30, 2024. The adjustment was recorded as a result of the State of Connecticut Superior Court’s decision on the rate case appeal on March 25, 2024. The impacts primarily include a reduction to depreciation expense to reflect lower depreciation rates ordered by PURA in its final decision, partially offset by a reserve recorded for revenues subject to refund as a result of the lower authorized revenues not yet reflected in current rates. The earnings increase was partially offset by higher interest expense, higher depreciation expense, and higher operations and maintenance expense.
Eversource Parent and Other Companies: Eversource parent and other companies’ losses improved by $293.6 million and $275.8 million in the second quarter and the first half of 2024, respectively, as compared to the second quarter and the first half of 2023, due primarily to the absence of the impairment of Eversource parent’s offshore wind investments in the second quarter of 2023, which resulted in an after-tax charge of $331.0 million, or $0.95 per share and the absence of a loss on the disposition of land in the second quarter of 2023 that was initially acquired to construct the Northern Pass Transmission project and was subsequently abandoned. These earnings improvements were partially offset by higher interest expense in both periods. Additionally, earnings in the second quarter were negatively impacted by a higher effective tax rate.
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 totaled $33.4 million as of June 30, 2024, compared with $53.9 million as of December 31, 2023.
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 13, 2028. 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 13, 2028, that 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
| June 30, 2024 |  | December 31, 2023 |  | June 30, 2024 |  | December 31, 2023 |  | June 30, 2024 |  | December 31, 2023
(Millions of Dollars) |  |  |  |  |
Eversource Parent Commercial Paper Program | $ | 1,203.0 |  |  | $ | 1,771.9 |  |  | $ | 797.0 |  |  | $ | 228.1 |  |  | 5.67 | % |  | 5.60 | %
NSTAR Electric Commercial Paper Program | 236.5 |  |  | 365.8 |  |  | 413.5 |  |  | 284.2 |  |  | 5.37 | % |  | 5.40 | %

There were no borrowings outstanding on the revolving credit facilities as of June 30, 2024 or December 31, 2023.
CL&P and PSNH have uncommitted line of credit agreements totaling $375 million and $250 million, respectively, all of which will expire in either October 2024, May 2025 or September 2025. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of June 30, 2024.
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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 CL&P long-term debt issuance in January 2024, $207.3 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt on Eversource parent’s balance sheet as of December 31, 2023. As a result of the Yankee Gas long-term debt issuances in July 2024, $37.9 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2024.
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, 2024, there were intercompany loans from Eversource parent to CL&P of $407.8 million and to PSNH of $132.0 million. As of December 31, 2023, there were intercompany loans from Eversource parent to CL&P of $457.0 million and to PSNH of $233.0 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time. As a result of the CL&P long-term debt issuance in January 2024, $207.3 million of CL&P’s intercompany borrowings were reclassified to Long-Term Debt on CL&P’s balance sheet as of December 31, 2023.
Long-Term Debt Issuance Authorizations: On February 8, 2024, the NHPUC approved PSNH’s request for authorization to issue up to $300 million in long-term debt through December 31, 2024. On May 1, 2024, the DPU approved NSTAR Electric’s request for authorization to issue up to $2.4 billion in long-term debt through December 31, 2026. On July 24, 2024, PURA approved CL&P’s request for authorization to issue up to $1.0 billion in long-term debt through December 31, 2025.
Long-Term Debt Issuances and Repayments: The following table summarizes long-term debt issuances and repayments:

(Millions of Dollars) | Interest Rate |  | Issuance/(Repayment) |  | Issue Date or Repayment Date |  | Maturity Date |  | Use of Proceeds for Issuance/ Repayment Information
CL&P 2024 Series A First Mortgage Bonds | 4.65 | % |  | $ | 350.0 |  |  | January 2024 |  | January 2029 |  | Repaid short-term debt, paid capital expenditures and working capital
NSTAR Electric 2024 Debentures | 5.40 | % |  | 600.0 |  |  | May 2024 |  | June 2034 |  | Repaid short-term debt, paid capital expenditures and working capital
PSNH Series X First Mortgage Bonds | 5.35 | % |  | 300.0 |  |  | April 2024 |  | October 2033 |  | Repaid short-term debt, paid capital expenditures and working capital
Eversource Parent Series DD Senior Notes | 5.00 | % |  | 350.0 |  |  | January 2024 |  | January 2027 |  | Repaid short-term debt
Eversource Parent Series EE Senior Notes | 5.50 | % |  | 650.0 |  |  | January 2024 |  | January 2034 |  | Repaid short-term debt
Eversource Parent Series FF Senior Notes | 5.85 | % |  | 700.0 |  |  | April 2024 |  | April 2031 |  | Repay Series X Senior Notes and Aquarion’s 2014 Senior Notes at maturity and short-term debt
Eversource Parent Series GG Senior Notes | 5.95 | % |  | 700.0 |  |  | April 2024 |  | July 2034 |  | Repay Series X Senior Notes and Aquarion’s 2014 Senior Notes at maturity and short-term debt
Eversource Parent Series X Senior Notes | 4.20 | % |  | (900.0) |  |  | June 2024 |  | June 2024 |  | Paid at maturity
NSTAR Gas Series W First Mortgage Bonds | 5.29 | % |  | 160.0 |  |  | June 2024 |  | June 2029 |  | Repaid short-term debt, paid capital expenditures and general corporate purchases
NSTAR Gas Series X First Mortgage Bonds | 5.48 | % |  | 40.0 |  |  | June 2024 |  | June 2034 |  | Repaid short-term debt, paid capital expenditures and general corporate purchases
Yankee Gas Series W First Mortgage Bonds | 5.50 | % |  | 90.0 |  |  | July 2024 |  | July 2029 |  | Repaid short-term debt, paid capital expenditures, working capital and repay Series P bonds at maturity
Yankee Gas Series X First Mortgage Bonds | 5.74 | % |  | 90.0 |  |  | July 2024 |  | July 2034 |  | Repaid short-term debt, paid capital expenditures, working capital and repay Series P bonds at maturity

As a result of the Yankee Gas long-term debt issuances in July 2024, $100.0 million of current portion of long-term debt was reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2024.
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 $7.6 million of interest payments in the first half of 2024, and paid $21.6 million of RRB principal payments and $8.3 million of interest payments in the first half of 2023.
Common Share Issuances and 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. In the first six months of 2024, Eversource issued 4,206,649 common shares, which resulted in proceeds of $248.2 million, net of issuance costs. Eversource used the net proceeds received for general corporate purposes.
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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 $962.0 million in the first half of 2024, compared with $647.3 million in the first half of 2023. Operating cash flows were favorably impacted by the timing of cash payments made on our accounts payable, the timing of other working capital items, a decrease in cost of removal expenditures, a $48.8 million increase in income tax refunds received in 2024 compared to 2023, and a $42.6 million decrease in cash payments to vendors for storm costs. These favorable impacts were partially offset by the timing of cash collections on our accounts receivable and an increase in regulatory under-recoveries driven primarily by the timing of collections for energy and natural gas supply costs and other regulatory tracking mechanisms. The impacts of regulatory collections are included in both Regulatory Recoveries and Amortization on the statements of cash flows.
On April 17, 2024, PURA issued an interim decision in CL&P’s Rate Adjustment Mechanisms (RAM) filing and approved rates for six RAM components, with rates effective July 1, 2024 through April 30, 2025. The rate approvals include the recovery of NBFMCC and SBC net underrecoveries as of December 31, 2023 of $264.9 million and $86.2 million, respectively, and the recovery of expected net costs of $388.5 million for the NBFMCC and $254.4 million for the SBC for the period July 1, 2024 through April 30, 2025. The NBFMCC rate adjustment is primarily driven by long-term nuclear power purchase agreements required by state policy and the SBC rate adjustment is primarily driven by costs associated with accounts receivable hardship customer protection and the new low-income discount rate effective December 2023. On July 23, 2024, PURA issued a draft final decision that approved a further adjustment to the NBFMCC rate to include the recovery of incurred and deferred electric vehicle program costs from 2021 through May 31, 2024 of $44.4 million and expected electric vehicle program costs from June 1, 2024 through December 31, 2024 of $24.3 million. In total, $49.8 million, including $5.4 million in carrying costs, will be recovered over a 20-month period of September 1, 2024 through April 30, 2026, and $24.3 million will be recovered over an eight-month period of September 1, 2024 through April 30, 2025. In addition, PURA approved $3.5 million of 2024 Innovative Energy Solutions program costs and $2.5 million of Connecticut Green Bank program costs, over an eight-month period of September 1, 2024 through April 30, 2025. A final PURA decision in CL&P’s RAM filing is expected on August 14, 2024.
On May 1, 2024, our Board of Trustees approved a common share dividend payment of $0.715 per share, paid on June 28, 2024 to shareholders of record as of May 16, 2024. In the first half of 2024, we paid cash dividends of $490.9 million and issued non-cash dividends of $12.0 million in the form of treasury shares, totaling dividends of $502.9 million. In the first half of 2023, we paid cash dividends of $459.0 million and issued non-cash dividends of $11.8 million in the form of treasury shares, totaling dividends of $470.8 million.
Eversource issues treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan.
In the first half of 2024, CL&P, NSTAR Electric and PSNH paid $82.5 million, $393.9 million and $62.0 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 of 2024, investments for Eversource, CL&P, NSTAR Electric, and PSNH were $2.22 billion, $532.2 million, $729.8 million, and $289.7 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.
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 2023 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, there have been no material changes to our cash requirements from contractual obligations and payment schedules previously disclosed in our 2023 Form 10-K.
Credit Ratings: On June 18, 2024, Moody’s revised the outlook from stable to negative for CL&P.
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 $2.26 billion in the first half of 2024, compared to $1.98 billion in the first half of 2023. These amounts included $152.7 million and $119.1 million in the first half of 2024 and 2023, 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 $135.6 million in the first half of 2024, as compared to the first half of 2023. A summary of electric transmission capital expenditures by company is as follows:

| For the Six Months Ended June 30,
(Millions of Dollars) | 2024 |  | 2023
CL&P | $ | 259.2 |  |  | $ | 162.9 |
NSTAR Electric | 235.1 |  |  | 227.4 |
PSNH | 199.7 |  |  | 168.1 |
Total Electric Transmission | $ | 694.0 |  |  | $ | 558.4 |

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Our transmission projects are designed to improve the reliability of the electric grid, meet customer demand for power, and strengthen the electric grid's resilience against extreme weather and other safety and security threats. 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.
Distribution Business: A summary of distribution capital expenditures is as follows:

| For the Six Months Ended June 30,
(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH |  | Total Electric |  | Natural Gas |  | Water |  | Total
2024 |  |  |  |  |  |  |  |  |  |  |  |  |
Basic Business | $ | 129.4 |  |  | $ | 229.6 |  |  | $ | 51.5 |  |  | $ | 410.5 |  |  | $ | 115.8 |  |  | $ | 10.8 |  |  | $ | 537.1 |
Aging Infrastructure | 101.5 |  |  | 145.9 |  |  | 22.5 |  |  | 269.9 |  |  | 324.3 |  |  | 67.0 |  |  | 661.2 |
Load Growth and Other | 59.4 |  |  | 107.3 |  |  | 24.4 |  |  | 191.1 |  |  | 22.6 |  |  | 0.4 |  |  | 214.1 |
Total Distribution | $ | 290.3 |  |  | $ | 482.8 |  |  | $ | 98.4 |  |  | $ | 871.5 |  |  | $ | 462.7 |  |  | $ | 78.2 |  |  | $ | 1,412.4 |
2023 |  |  |  |  |  |  |  |  |  |  |  |  |
Basic Business | $ | 135.9 |  |  | $ | 172.1 |  |  | $ | 38.7 |  |  | $ | 346.7 |  |  | $ | 93.9 |  |  | $ | 7.7 |  |  | $ | 448.3 |
Aging Infrastructure | 120.8 |  |  | 146.7 |  |  | 40.3 |  |  | 307.8 |  |  | 305.4 |  |  | 60.2 |  |  | 673.4 |
Load Growth and Other | 62.1 |  |  | 80.0 |  |  | 11.9 |  |  | 154.0 |  |  | 26.9 |  |  | 0.3 |  |  | 181.2 |
Total Distribution | $ | 318.8 |  |  | $ | 398.8 |  |  | $ | 90.9 |  |  | $ | 808.5 |  |  | $ | 426.2 |  |  | $ | 68.2 |  |  | $ | 1,302.9 |

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.
Offshore Wind Business: As of June 30, 2024, Eversource’s offshore wind business includes 50 percent ownership interests in wind partnerships, which collectively hold the Revolution Wind, South Fork Wind and Sunrise Wind projects, and a tax equity investment in South Fork Wind. The offshore wind projects are being developed and constructed through joint and equal partnerships with Ørsted.
As of June 30, 2024 and December 31, 2023, Eversource's total equity investment balance in its offshore wind business was $806.1 million and $515.5 million, respectively.
On May 25, 2023, Eversource announced that it had completed a strategic review of its offshore wind investments and determined that it would pursue the sale of its offshore wind investments. On September 7, 2023, Eversource completed the sale of its 50 percent interest in an uncommitted lease area consisting of approximately 175,000 developable acres located 25 miles off the south coast of Massachusetts to Ørsted for $625 million in an all-cash transaction.
In September of 2023, Eversource made a contribution of $528 million using the proceeds from the lease area sale to invest in a tax equity interest for South Fork Wind. South Fork Wind was restructured as a tax equity investment, with Eversource purchasing 100 percent ownership of a new Class A tax equity membership interest. This investment will result in Eversource receiving cash flow benefits from investment tax credits (ITC) and other future cash flow benefits as well. As of June 30 2024, all twelve South Fork Wind turbines met the requirements to qualify for the investment tax credits. As a result, $385 million of expected investment tax credits were reclassified from the South Fork Wind tax equity investment balance reported in Investments in Unconsolidated Affiliates as a reduction in current taxes payable of $54 million and an increase in deferred tax assets of $331 million on the Eversource balance sheet as of June 30, 2024.
As a result of these investment tax credits generated from our wind investments, Eversource expects lower federal income tax payments between 2024 through 2026.
Sales of Offshore Wind Investments: On January 24, 2024, Ørsted signed an agreement with Eversource to acquire Eversource’s 50 percent share of Sunrise Wind, subject to the successful selection of Sunrise Wind in the New York fourth solicitation for offshore wind capacity, signing of an OREC contract with NYSERDA, finalization of agreements including the equity and asset purchase agreement, receipt of the final approval by BOEM of the Sunrise Wind Construction and Operations Plan (COP), and relevant regulatory approvals. On February 29, 2024, Sunrise Wind was selected for contract negotiation in the offshore wind solicitation by NYSERDA, and was subsequently awarded a contract, which was finalized and completed on May 31, 2024. In June 2024, Sunrise Wind received final approval by BOEM of its COP and all remaining regulatory approvals.
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On April 18, 2024, Eversource and Ørsted executed the equity and asset purchase agreement to sell Eversource’s 50 percent interest in Sunrise Wind to Ørsted for a gross purchase price of $230 million. The purchase price was subject to reduction for actual capital spending less than forecasted spending between signing the agreement in January and closing of the transaction. On July 9, 2024, Eversource completed the sale of its 50 percent ownership share of Sunrise Wind to Ørsted. In accordance with the equity and asset purchase agreement and after adjustment for the reduction in capital spending compared to forecasted, Ørsted paid Eversource $118 million at the closing of the sale transaction, and the remaining proceeds of $34 million will be paid after onshore construction is completed and certain other construction milestones are achieved.
With the completion of the sale, Eversource has divested all of its ownership interest in Sunrise Wind and will not have any ongoing ownership interest in the project, nor any ongoing financial obligations associated with project costs. Eversource’s existing credit support obligations were either terminated or indemnified by Ørsted as a result of the sale. Eversource has entered into a separate amended and restated construction management agreement to manage Sunrise Wind’s onshore construction through completion. In this role, Eversource will solely be a service provider to Sunrise Wind.
On February 13, 2024, Eversource executed an agreement to sell its existing 50 percent interests in the South Fork Wind and Revolution Wind projects to Global Infrastructure Partners (GIP) for $1.1 billion of cash proceeds to be received upon closing, subject to adjustment. The purchase price is inclusive of the sales value related to a 40 percent level of federal investment tax credits, 10 percent of which is the energy community ITC adder of approximately $170 million related to Revolution Wind. The purchase price is subject to adjustments based on, among other things, the progress, timing and the construction cost of Revolution Wind, including changes in actual versus forecasted capital spending between signing the agreement and closing of the transaction. Factors that could result in Eversource’s total net proceeds from the transaction to be lower, resulting in post-closing adjustment payments owed to GIP, include the ultimate cost of construction and extent of cost overruns for Revolution Wind, delays in constructing Revolution Wind, which would impact the economics associated with the purchase price adjustment, and Revolution Wind’s eligibility for federal investment tax credits at less than the value included in the purchase price. Total net proceeds could also be adjusted for a benefit due to Eversource if there are lower operation costs or higher availability of the projects through the period that is four years following the commercial operation date of the Revolution Wind project.
The post-closing purchase price adjustment payments include cost sharing obligations that provide Eversource will share equally with GIP in GIP’s funding obligations for up to approximately $240 million of incremental capital expenditure overruns incurred during the construction phase for Revolution Wind, after which obligations for any additional capital expenditure overruns would be shared equally by Eversource and Ørsted. The purchase price is also subject to post-closing adjustments as a result of final project economics, which includes Eversource’s obligation to maintain GIP’s internal rate of return for each project as specified in the agreement. Post-closing purchase price adjustment payments will be made following the sale closing date for South Fork and following the commercial operation of Revolution Wind. South Fork Wind construction has been completed, and Eversource does not expect any material cost sharing or other purchase price adjustment payments for South Fork Wind.
Closing the transaction with GIP is subject to customary conditions, including certain regulatory approvals, as well as other conditions, among which is the completion and execution of the partnership agreements between GIP and Ørsted that will govern GIP’s new ownership interest in those projects following Eversource’s divestiture. All regulatory approvals have been received and the review period under the Hart Scott Rodino Act has expired. Closing of this transaction is currently expected to occur in the third quarter of 2024.
Under the agreement with GIP, Eversource’s existing credit support obligations are expected to roll off for each project around the time that each project completes its expected capital spend. Eversource will continue to make future cash expenditures for required cash contributions up to the time of disposition of the Revolution Wind and South Fork Wind projects and changes in the timing and amounts of these contributions would be adjusted in the purchase price.
Upon close of the sale transactions in the third quarter of 2024, the total proceeds will be compared to the current carrying value of the investments, and the difference will be reflected in the statement of income. At that time, Eversource will also record an estimate of future obligations under the terms of the GIP transaction, which primarily could include the potential cost overrun sharing obligation and potential obligation to maintain GIP’s internal rate of return for the Revolution Wind project. Eversource is currently evaluating the combined impact of the Sunrise Wind sale and the expected sale of Revolution Wind and South Fork Wind, and at this time, does not expect a material financial impact on our 2024 results. Proceeds from the transactions will be used to pay off parent company debt.
Impairment: Equity method investments are assessed for impairment when conditions exist as of the balance sheet date that indicate that the fair value of the investment may be 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. If the decline in value is considered to be other-than-temporary, the investment is written down to its estimated fair value, which establishes a new cost basis in the investment. Subsequent declines or recoveries after the reporting date are not considered in the impairment recognized. Investments that are other-than-temporarily impaired and written down to their estimated fair value cannot subsequently be written back up for increases in estimated fair value. Impairment evaluations involve a significant degree of judgment and estimation, including identifying circumstances that indicate an impairment may exist at the equity method investment level, selecting discount rates used to determine fair values, and developing an estimate of discounted future cash flows expected from investment operations or the sale of the investment. In the second quarter of 2024, there were no indicators of an other-than-temporary impairment in Eversource’s equity method investment balance.
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In the second quarter of 2023, in connection with the process to divest its offshore wind business, Eversource identified indicators for impairment. In the impairment assessment, Eversource evaluated its investments and determined that the carrying value of the equity method offshore wind investments exceeded the fair value of the investments and that the decline in fair value was other-than-temporary. The completion of the strategic review in the second quarter of 2023 resulted in Eversource recording a pre-tax other-than-temporary impairment charge of $401 million ($331 million after-tax) to reflect the investment at estimated fair value based on the expected purchase price at that time. In the fourth quarter of 2023, Eversource recognized an additional pre-tax other-than-temporary impairment charge of $1.77 billion ($1.62 billion after-tax) in its offshore wind investments and established a new cost basis in the investments as of December 31, 2023. The impairment charges were non-cash charges and did not impact Eversource’s cash position.
Permitting and Construction of Offshore Wind Projects: The offshore wind projects require 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. South Fork Wind, Revolution Wind and Sunrise Wind have each received final federal approval from BOEM. All state and local approvals have been received for South Fork and Revolution Wind. For Sunrise Wind, all state and local approvals required to start construction have been received.
Installation of South Fork Wind’s twelve 11-megawatt wind turbines was completed in February 2024 and the project is in-service. For Revolution Wind, major construction began in the fourth quarter of 2023 and onshore and offshore construction is underway. For Sunrise Wind, onshore construction is in progress.
FERC Regulatory Matters
FERC ROE Complaints: Four separate complaints were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively, the Complainants). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive (incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.
The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, FERC issued Opinion No. 531-A and set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the Court).
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, 2024 and December 31, 2023. 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, 2024 and December 31, 2023.
On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.
The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.
If the results of the illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order.
On November 21, 2019, FERC issued Opinion No. 569 affecting the two pending transmission ROE complaints against the Midcontinent ISO (MISO) transmission owners, in which FERC adopted a new methodology for determining base ROEs. Various parties sought rehearing. On December 23, 2019, the NETOs filed supplementary materials in the NETOs' four pending cases to respond to this new methodology because of the uncertainty of the applicability to the NETOs' cases. On May 21, 2020, the FERC issued its order in Opinion No. 569-A on the rehearing of the MISO transmission owners' cases, in which FERC again changed its methodology for determining the MISO transmission owners' base ROEs. On November 19, 2020, the FERC issued Opinion No. 569-B denying rehearing of Opinion No. 569-A and reaffirmed the methodology previously adopted in Opinion No. 569-A. The new methodology differs significantly from the methodology proposed by FERC in its October 16, 2018 order to determine the NETOs' base ROEs in its four pending cases. FERC Opinion Nos. 569-A and 569-B were appealed to the Court. On August 9, 2022, the Court issued its decision vacating MISO ROE FERC Opinion Nos. 569, 569-A and 569-B and remanded to FERC to reopen the proceedings. The Court found that FERC’s development of the new return methodology was arbitrary and capricious due to FERC’s failure to offer a reasonable explanation for its decision to reintroduce the risk-premium financial model in its new methodology for calculating a just and reasonable return. At this time, Eversource cannot predict how and when FERC will address the Court’s findings on the remand of the MISO FERC opinions or any potential associated impact on the NETOs’ four pending ROE complaint cases.
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Given the significant uncertainty regarding the applicability of the FERC opinions in the MISO transmission owners’ two complaint cases to the NETOs’ pending four complaint cases, Eversource concluded that there is no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods at this time. As well, Eversource cannot reasonably estimate a range of loss for any of the four complaint proceedings at this time. Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.
A change of 10 basis points to the base ROE used to establish the reserves would impact Eversource’s after-tax earnings by an average of approximately $3 million for each of the four 15-month complaint periods. Prospectively from the date of a final FERC order implementing a new base ROE, based off of 2023 rate base, a change of 10 basis points to the base ROE would impact Eversource’s future annual after-tax earnings by approximately $5.5 million per year, and will increase slightly over time as we continue to invest in our transmission infrastructure.
FERC Notice of Proposed Rulemaking on Transmission Incentives: 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 2023 rate base) on Eversource's after-tax earnings is approximately $20 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 of 2024, changes made to the regulated companies’ rates did not have a material impact on their earnings. For further information, see "Financial Condition and Business Analysis – Regulatory Developments and Rate Matters" included in Item 7, "Management’s Discussion and Analysis of Financial Condition and Results of Operations," of the Eversource 2023 Form 10-K.
Connecticut:
Aquarion Water Company of Connecticut Distribution Rate Case: On August 29, 2022, Aquarion Water Company of Connecticut (AWC-CT) filed an application with PURA to amend its existing rate schedules to address an operating revenue deficiency. AWC-CT’s rate application requested approval of rate increases of $27.5 million, an additional $13.6 million, and an additional $8.8 million, effective March 15, 2023, 2024, and 2025, respectively. On March 15, 2023, PURA issued a final decision that rejected this request. In this decision, PURA ordered a decrease to total authorized revenues of $4.0 million effective March 15, 2023. The decision allows an authorized regulatory ROE of 8.70 percent. On March 30, 2023, AWC-CT filed an appeal on the decision and requested a stay of the decision with the State of Connecticut Superior Court. On April 5, 2023, the Court temporarily granted AWC-CT’s request to stay and on May 25, 2023 granted a permanent stay of certain orders affecting base rates, which would keep existing rates in place until the appeal is completed. The stay included the condition that AWC-CT place any revenue received from customers above the rates and amounts authorized in the March 15, 2023 decision in a separate, interest bearing account until further order. On March 25, 2024, the State of Connecticut Superior Court issued a decision on the appeal which dismissed nine, remanded back to PURA two, and partially remanded one of AWC-CT’s twelve claims of error in its appeal. On March 28, 2024, AWC-CT filed an appeal of the Connecticut Superior Court decision to the Connecticut Appellate Court and that appeal was subsequently transferred to the Connecticut Supreme Court for review. A ruling on the appeal is pending.
On April 18, 2024, PURA initiated a docket to address the matters on remand. On July 31, 2024, PURA issued a final decision in this docket and increased AWC-CT’s approved revenue requirement by $0.1 million above the amount authorized in the March 15, 2023 decision. As a result of the State of Connecticut Superior Court’s decision on the appeal, AWC-CT recorded the impacts of the PURA rate case decision from the effective date of the order on March 15, 2023 through June 30, 2024. The impacts primarily include a reduction to depreciation expense to reflect lower depreciation rates ordered by PURA in its 2023 final decision, partially offset by a reserve recorded for revenues subject to refund as a result of the lower authorized revenues not yet reflected in current rates. These adjustments resulted in an after-tax benefit of $6.3 million recorded in the first half of 2024.
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Massachusetts:
NSTAR Electric Distribution Rates: NSTAR Electric’s PBR mechanism allows for an annual adjustment to base distribution rates for inflation, exogenous events and future capital additions based on a historical five-year average of total capital additions. On December 26, 2023, the DPU approved a $104.9 million increase to base distribution rates effective January 1, 2024. The base distribution rate increase was comprised of a $50.6 million inflation-based adjustment and a $54.3 million K-bar adjustment for capital additions based on the difference between the historical five-year average of total capital additions and the base capital revenue requirement.
NSTAR Gas Distribution Rates: NSTAR Gas’ PBR mechanism allows for an annual adjustment to base distribution rates for inflation and exogenous events. NSTAR Gas submitted its third annual PBR Adjustment filing on September 15, 2023 and on October 30, 2023, the DPU approved a $25.4 million increase to base distribution rates, of which, $15.5 million was associated with a base rate adjustment and the remainder for a prior period exogenous cost adjustment, for effect on November 1, 2023.
EGMA Distribution Rates: On May 29, 2024, EGMA filed for its first rate base reset for rates to be effective November 1, 2024, in accordance with an October 7, 2020 EGMA Rate Settlement Agreement approved by the DPU. The rate base reset occurring on November 1, 2024 adjusts distribution rates to account for capital additions (including the roll-in of GSEP capital additions), depreciation expense, property taxes, and return on rate base for capital additions placed into service through December 31, 2023. The total revenue requirement calculated for the first rate base reset is an increase to base distribution rates of $155.0 million, of which $34.1 million is associated with GSEP investments through December 31, 2023. Under the terms of the Rate Settlement Agreement, EGMA applied a cap on the revenue change to be effective November 1, 2024, and the amount in excess of the cap will be deferred for recovery through the Local Distribution Adjustment Clause (LDAC) on November 1, 2025, including carrying charges. After adjusting for the cap, the increase to base distribution rates is $87.5 million to be effective November 1, 2024 (of which $8.8 million is offset by a reduction in the GSEP revenue requirement and GSEP rate also taking effect on November 1, 2024), and an increase of $67.5 million to base distribution rates to be effective November 1, 2025.
NSTAR Electric CIP Filing: On December 30, 2022, the DPU approved a provisional system planning tariff for the recovery of costs associated with a capital investment project (CIP) proposal submitted by NSTAR Electric for one of six geographic study areas in its service territory in accordance with DPU’s directives. The DPU established a new, provisional framework for planning and funding upgrades to the electric power system to foster development and interconnection of distributed energy facilities. Under the DPU program, NSTAR Electric has filed infrastructure upgrade proposals to be built within a four-year construction timeframe that allocate the costs of interconnection upgrades between the interconnecting distributed generation facility and distribution customers based on a technical analysis of capacity benefits. Payments made by the distributed generation facility will be applied against the total capital investment made by NSTAR Electric and NSTAR Electric will earn a return on the net investment. The amount allocated to distribution customers will be recovered through a reconciling mechanism, the Provisional System Planning Tariff. The DPU approved the first of these provisional system planning projects, the Marion-Fairhaven group study area, which will enable 141 MW of distributed energy resources (DER) to be interconnected at a total estimated cost of $120 million. Of the total $120 million, $66 million will be allocated to distribution customers, once the enabled distributed energy facilities capacity is fully subscribed by distributed energy facilities interconnecting customers. Additionally, NSTAR Electric will proceed with construction of approximately $54 million of transmission upgrades necessary to improve local reliability and integrate distribution energy resources in the Marion-Fairhaven area and recover the amount through local transmission rates.
On June 4, 2024, the DPU approved four of the remaining five CIPs that were originally submitted by NSTAR Electric. These included the Plainfield-Blandford CIP, which will enable 40 MW of DER to be interconnected at a total estimated distribution investment of $37 million, the Dartmouth-Westport CIP which enables 60 MW of DER for a total distribution investment of $58 million, the Plymouth CIP which enables 380 MW of DER for a total distribution investment of $152 million and the Cape Cod CIP which enables 296 MW of DER for a total distribution investment of $170 million. Of the total $417 million for these four recently approved CIPs, $183 million will be allocated to distribution customers, once the enabled distributed energy facilities capacity is fully subscribed by distributed energy facilities interconnecting customers. Additionally, NSTAR Electric will proceed with construction of approximately $64 million of transmission upgrades necessary to improve local reliability and integrate distribution energy resources in the four CIP areas and recover the amount through local transmission rates. The sixth and final originally filed CIP, Freetown, is still pending approval with the DPU.
New Hampshire:
PSNH Distribution Rate Case: On June 11, 2024, PSNH filed an application with the NHPUC for approval of a temporary annual base distribution rate increase, proposed to take effect August 1, 2024. On July 31, 2024, the NHPUC approved a settlement agreement that was reached by PSNH, New Hampshire Department of Energy, and the Office of the Consumer Advocate to implement a temporary annual base distribution rate increase of $61.2 million to take effect August 1, 2024.
Also on June 11, 2024, PSNH filed an application with the NHPUC to request an increase in permanent base distribution rates of $181.9 million, which is inclusive of the temporary rate increase, and proposed to take effect August 1, 2025. The temporary rates are subject to reconciliation based on the outcome of the permanent rate case back to the date when temporary rates took effect. The permanent rate increase request includes $247 million in unrecovered storm costs to be recovered over a five-year period. As part of the rate case, PSNH proposed to implement a performance-based rate making plan that would adjust rates annually over a four-year term with a corresponding stay out provision. The plan includes a revenue-cap formula adjusted for inflation, a supplemental capital adjustment formula to support PSNH’s planned capital infrastructure improvements, an exogenous events recovery mechanism, performance metrics and an earnings sharing mechanism, among others. The NHPUC is permitted up to twelve months in all to investigate the proposed rates and issue a final order. A decision by the NHPUC on permanent rates is expected by August 1, 2025.
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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 2023 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, 2024 and 2023 included in this combined Quarterly Report on Form 10-Q:

| For the Three Months Ended June 30, |  | For the Six Months Ended June 30,
(Millions of Dollars) | 2024 |  | 2023 |  | Increase/(Decrease) |  | 2024 |  | 2023 |  | Increase/(Decrease)
Operating Revenues | $ | 2,533.5 |  |  | $ | 2,629.3 |  |  | $ | (95.8) |  |  | $ | 5,866.1 |  |  | $ | 6,425.0 |  |  | $ | (558.9) |
Operating Expenses: |  |  |  |  |  |  |  |  |  |  |
Purchased Power, Purchased Natural Gas and Transmission | 841.4 |  |  | 1,161.1 |  |  | (319.7) |  |  | 2,077.4 |  |  | 3,064.3 |  |  | (986.9) |
Operations and Maintenance | 464.4 |  |  | 427.3 |  |  | 37.1 |  |  | 927.4 |  |  | 881.9 |  |  | 45.5 |
Depreciation | 354.6 |  |  | 320.0 |  |  | 34.6 |  |  | 694.5 |  |  | 632.9 |  |  | 61.6 |
Amortization | (114.1) |  |  | (218.5) |  |  | 104.4 |  |  | (116.5) |  |  | (294.5) |  |  | 178.0 |
Energy Efficiency Programs | 145.3 |  |  | 145.8 |  |  | (0.5) |  |  | 358.8 |  |  | 368.8 |  |  | (10.0) |
Taxes Other Than Income Taxes | 239.4 |  |  | 232.9 |  |  | 6.5 |  |  | 476.0 |  |  | 461.4 |  |  | 14.6 |
Total Operating Expenses | 1,931.0 |  |  | 2,068.6 |  |  | (137.6) |  |  | 4,417.6 |  |  | 5,114.8 |  |  | (697.2) |
Operating Income | 602.5 |  |  | 560.7 |  |  | 41.8 |  |  | 1,448.5 |  |  | 1,310.2 |  |  | 138.3 |
Interest Expense | 271.3 |  |  | 207.4 |  |  | 63.9 |  |  | 522.1 |  |  | 401.8 |  |  | 120.3 |
Impairment of Offshore Wind Investment | — |  |  | 401.0 |  |  | (401.0) |  |  | — |  |  | 401.0 |  |  | (401.0) |
Other Income, Net | 115.3 |  |  | 94.9 |  |  | 20.4 |  |  | 206.3 |  |  | 183.9 |  |  | 22.4 |
Income Before Income Tax Expense | 446.5 |  |  | 47.2 |  |  | 399.3 |  |  | 1,132.7 |  |  | 691.3 |  |  | 441.4 |
Income Tax Expense | 109.3 |  |  | 29.9 |  |  | 79.4 |  |  | 271.7 |  |  | 180.9 |  |  | 90.8 |
Net Income | 337.2 |  |  | 17.3 |  |  | 319.9 |  |  | 861.0 |  |  | 510.4 |  |  | 350.6 |
Net Income Attributable to Noncontrolling Interests | 1.9 |  |  | 1.9 |  |  | — |  |  | 3.8 |  |  | 3.8 |  |  | — |
Net Income Attributable to Common Shareholders | $ | 335.3 |  |  | $ | 15.4 |  |  | $ | 319.9 |  |  | $ | 857.2 |  |  | $ | 506.6 |  |  | $ | 350.6 |

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

| Electric |  | Firm Natural Gas |  | Water
| Sales Volumes (GWh) |  | Percentage Increase |  | Sales Volumes (MMcf) |  | Percentage Increase |  | Sales Volumes (MG) |  | Percentage Increase/ (Decrease)
Three Months Ended June 30: | 2024 |  | 2023 |  |  | 2024 |  | 2023 |  |  | 2024 |  | 2023 |
Traditional | 1,836 |  |  | 1,745 |  |  | 5.2 | % |  | — |  |  | — |  |  | — | % |  | 376 |  |  | 370 |  |  | 1.6 | %
Decoupled and Special Contracts (1) | 10,051 |  |  | 9,419 |  |  | 6.7 | % |  | 24,814 |  |  | 23,751 |  |  | 4.5 | % |  | 5,601 |  |  | 6,000 |  |  | (6.7) | %
Total Sales Volumes | 11,887 |  |  | 11,164 |  |  | 6.5 | % |  | 24,814 |  |  | 23,751 |  |  | 4.5 | % |  | 5,977 |  |  | 6,370 |  |  | (6.2) | %
Six Months Ended June 30: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Traditional | 3,784 |  |  | 3,645 |  |  | 3.8 | % |  | — |  |  | — |  |  | — | % |  | 719 |  |  | 679 |  |  | 5.9 | %
Decoupled | 20,639 |  |  | 19,717 |  |  | 4.7 | % |  | 86,349 |  |  | 83,534 |  |  | 3.4 | % |  | 10,408 |  |  | 10,592 |  |  | (1.7) | %
Total Sales Volumes | 24,423 |  |  | 23,362 |  |  | 4.5 | % |  | 86,349 |  |  | 83,534 |  |  | 3.4 | % |  | 11,127 |  |  | 11,271 |  |  | (1.3) | %

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Weather, fluctuations in energy supply rates, 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: The variance in Operating Revenues by segment is as follows:

(Millions of Dollars) | Three Months Ended |  | Six Months Ended
Electric Distribution | $ | (88.1) |  |  | $ | (415.0) |
Natural Gas Distribution | (15.6) |  |  | (154.8) |
Electric Transmission | 54.0 |  |  | 103.1 |
Water Distribution | (0.6) |  |  | (0.6) |
Other | (13.6) |  |  | 16.1 |
Eliminations | (31.9) |  |  | (107.7) |
Total Operating Revenues | $ | (95.8) |  |  | $ | (558.9) |

Electric and Natural Gas Distribution Revenues:
Base Distribution Revenues:
•Base electric distribution revenues increased $28.5 million and $56.6 million for the three and six month periods due primarily to a base distribution rate increase at NSTAR Electric effective January 1, 2024.
•Base natural gas distribution revenues increased $4.6 million and $14.2 million for the three and six month periods due primarily to a base distribution rate increase at NSTAR Gas effective November 1, 2023.
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. 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. 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. 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 their 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 utility 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 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 their 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.
The variance in tracked distribution revenues for the three and six month periods is due primarily to the following:

| Electric Distribution |  | Natural Gas Distribution
(Millions of Dollars) | Three Months Ended |  | Six Months Ended |  | Three Months Ended |  | Six Months Ended
Retail Tariff Tracked Revenues: |  |  |  |  |  |  |
Energy supply procurement | $ | (341.6) |  |  | $ | (855.6) |  |  | $ | (30.5) |  |  | $ | (196.9) |
CL&P FMCC | 80.0 |  |  | 157.9 |  |  | — |  |  | — |
Retail transmission | 43.9 |  |  | 91.1 |  |  | — |  |  | — |
Net Metering | 29.2 |  |  | 59.5 |  |  | — |  |  | — |
Other distribution tracking mechanisms | 50.5 |  |  | 103.9 |  |  | 14.8 |  |  | 24.1 |
Wholesale Market Sales Revenue | 19.7 |  |  | (32.3) |  |  | (4.8) |  |  | 4.4 |

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The decrease in energy supply procurement within both electric distribution and natural gas distribution for the three and six month periods was driven by lower average prices and lower average supply-related sales volumes.
The increase in CL&P’s FMCC revenues was driven by an increase in the retail Non-Bypassable Federally Mandated Congestion Charge (NBFMCC) rate. The CL&P NBFMCC rate includes the recovery of costs incurred under long-term state approved energy contracts with the Millstone and Seabrook nuclear power plants, net of the benefits received from selling this energy into the ISO-NE wholesale market. Effective January 1, 2023, CL&P reduced the average NBFMCC rate to a credit of $0.01524 per kWh. The rate reduction returned to customers the net benefits of higher wholesale market sales received in the ISO-NE market for these energy contracts. The average NBFMCC rate changed to $0.00000 per kWh effective July 1, 2023 and then to $0.00293 per kWh effective September 1, 2023. As a result of the April 2024 interim decision in the 2024 CL&P RAM filing, the average NBFMCC rate increased to $0.03906 per kWh effective July 1, 2024. As a result of the July 2024 draft final decision in the 2024 CL&P RAM filing, the average NBFMCC will increase to $0.04279 per kWh effective September 1, 2024. The rate increases primarily resulted from higher costs associated with power purchase agreements with the Millstone and Seabrook nuclear power plants.
Fluctuations in retail transmission revenues are driven by the recovery of the costs of our wholesale transmission business, such as those billed by ISO-NE and Local and Regional Network Service charges. For further information, see "Purchased Power, Purchased Natural Gas and Transmission” expense below.
Electric Transmission Revenues: Electric transmission revenues increased $54.0 million and $103.1 million for the three and six month periods due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure and the impact of the annual billing and cost reconciliation filing with FERC.
Other Revenues and Eliminations: Other revenues primarily include the revenues of Eversource's service company, most of which are eliminated in consolidation. Eliminations are also primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business in rates charged to their customers.
Purchased Power, Purchased Natural Gas and Transmission expense includes costs associated with providing electric generation service supply and natural gas to all customers who have not migrated to third party suppliers, the cost of energy purchase contracts entered into as required by regulation, and transmission costs. These electric and natural gas supply procurement costs, other energy-related costs, and transmission costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). The variance in Purchased Power, Purchased Natural Gas and Transmission expense is due primarily to the following:

(Millions of Dollars) | Three Months Ended |  | Six Months Ended
Energy supply procurement costs | $ | (341.4) |  |  | $ | (855.7) |
Other electric distribution costs | 67.9 |  |  | 79.7 |
Natural gas supply costs | (38.3) |  |  | (191.7) |
Transmission costs | 34.5 |  |  | 69.0 |
Eliminations | (42.4) |  |  | (88.2) |
Total Purchased Power, Purchased Natural Gas and Transmission | $ | (319.7) |  |  | $ | (986.9) |

The variance in energy supply procurement costs is offset in Operating Revenues (tracked energy supply procurement revenues). The variance in other electric distribution costs for the three and six month periods was primarily the result of higher net metering costs at NSTAR Electric, higher long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism at CL&P, partially offset by a decrease in long-term renewable energy purchase contract costs at PSNH.
Costs at the natural gas distribution segment relate to supply procurement costs for retail customers. Total natural gas costs decreased for the three and six month periods due primarily to a decrease in the retail cost deferral and lower average prices, partially offset by higher average purchased volumes.
The increase in transmission costs for the three month period was primarily the result of an increase in costs billed by ISO-NE that support regional grid investments. This was partially offset by a decrease in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network, and a decrease in the retail transmission cost deferral, which reflects the actual cost of transmission service compared to estimated amounts billed to customers. The increase in transmission costs for the six month period was primarily the result of an increase in costs billed by ISO-NE and an increase in Local Network Service charges. This was partially offset by a decrease in the retail transmission cost deferral.
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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). The variance in Operations and Maintenance expense is due primarily to the following:

(Millions of Dollars) | Three Months Ended |  | Six Months Ended
Base Electric Distribution (Non-Tracked Costs): |  |  |
Storm Costs | $ | 16.2 |  |  | $ | 16.3 |
Operations-related expenses (including vendor services, vehicles and materials) | 6.2 |  |  | 6.4 |
Employee-related expenses (including labor and benefits) | 5.6 |  |  | 4.8 |
Shared corporate costs (including IT system depreciation at Eversource Service) | 4.1 |  |  | 6.7 |
Vegetation management | 1.3 |  |  | 5.0 |
General costs (including vendor services in corporate areas, uncollectible expense, insurance, fees and assessments) | (1.3) |  |  | 1.4 |
Total Base Electric Distribution (Non-Tracked Costs) | 32.1 |  |  | 40.6 |
Tracked Electric Costs (Electric Distribution and Electric Transmission) - Increase in both periods due primarily to higher transmission expense | 20.7 |  |  | 47.2 |
Total Electric Distribution and Electric Transmission | 52.8 |  |  | 87.8 |
Natural Gas Distribution: |  |  |
Base (Non-Tracked Costs) - Decrease in both periods due primarily to lower employee-related expenses and lower uncollectible expense | (10.9) |  |  | (22.0) |
Tracked Costs | 5.8 |  |  | 6.1 |
Total Natural Gas Distribution | (5.1) |  |  | (15.9) |
Water Distribution | 1.8 |  |  | 5.3 |
Eversource Parent and Other Companies - other operations and maintenance | (23.8) |  |  | (13.9) |
Eliminations | 11.4 |  |  | (17.8) |
Total Operations and Maintenance | $ | 37.1 |  |  | $ | 45.5 |

Depreciation expen se increased for the three and six month periods due primarily to higher net plant in service balances.
Amortization expense includes the deferral of energy-related costs and other costs that are included in certain regulatory commission-approved cost tracking mechanisms. This deferral adjusts expense to match the corresponding revenues compared to the actual costs incurred. These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of cert ain costs as those costs are collected in rates.
The variance in Amortization for the three and six month periods is due primarily to the deferral adjustment of energy-related and other tracked costs at CL&P (included in the non-bypassable component of the FMCC mechanism), NSTAR Electric and PSNH, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The CL&P non-bypassable FMCC retail rate increased in the three and six month periods, and the higher collections lowered the regulatory under-recovery deferral adjustment recorded in the three and six month periods, resulting in an increase to amortization expense of $63.2 million and $116.3 million, respectively. Amortization expense also increased at NSTAR Electric as a result of an increase in storm costs recovered in rates and at PSNH due to the absence of a second quarter 2023 benefit related to the establishment of a new regulatory tracking mechanism that allowed for the recovery of previously incurred operating expenses associated with poles acquired from Consolidated Communications on May 1, 2023. The establishment of the PPAM regulatory asset resulted in a pre-tax benefit of $16.9 million recorded in Amortization expense on the statement of income in the second quarter of 2023.
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 includes a deferral adjustment that reflects the actual costs of energy efficiency programs compared to the amounts billed to customers, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. Energy Efficiency Programs expense decreased f or the six month period due primarily to the deferral adjustment, partially offset by higher program spending.
Taxes Other Than Income Taxes expen se increased for t he three and six month periods due primarily to higher property taxes as a result of higher utility plant balances and higher assessments, partially offset by lower Connecticut gross earnings taxes.
Interest Expense increased for the three and six month periods due primarily to an increase i n interest on long-term debt as a result of new debt issuances ($65.0 million and $120.5 million, respectively), an increase in interest expense on regulatory deferrals ($9.0 million and $13.1 million, respectively), and higher interest on short-term notes payable due to increased borrowings ($3.3 million and $11.4 million, respectively), partially offset by an increase in capitalized AFUDC related to debt funds and other capitalized interest ($14.0 million and $29.2 million, respectively).
Impairment of Offshore Wind Investment relates to an impairment charge in 2023 associated with Eversource’s equity method investment in its offshore wind business resulting from the completion of the strategic review to reflect the estimate of the fair value of the offshore wind projects. See "Business Development and Capital Expenditures – Offshore Wind Business" included in this Management's Discussion and Analysis of Financial Condition and Results of Operations.
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Other Income, Net increased for the three and six month periods due primarily to an increase in equity in earnings related to Eversource's equity method investments ($18.2 million and $22.2 million, respectively), an increase in interest income primarily from regulatory deferrals ($15.7 million and $22.6 million, respectively), an increase in capitalized AFUDC related to equity funds ($4.7 million and $16.0 million, respectively), the absence in 2024 of a loss on the disposition of land in the second quarter of 2023 ($6.5 million), and investment income in 2024 compared to investment losses in 2023 driven by market volatilit y ($2.5 million and $3.4 million, respectively), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($3.3 million and $10.3 million, respectively). Other Income, Net also decreased in both periods due to the absence in 2024 of a benefit in both the first and second quarter of 2023 from the liquidation of Eversource’s equity method investment in a renewable energy fund in excess of its carrying value, partially offset by a charitable contribution made with a portion of the proceeds from the liquidation in the first quarter of 2023.
Income Tax Expense increased for the three month period due primarily to higher pre-tax earnings ($83.8 million), higher state taxes ($25.8 million), a decrease in amortization of EDIT ($5.4 million), and an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($7.3 million), partially offset by a decrease in reserves ($42.9 million) primarily related to the 2023 impairment of Eversource’s offshore wind investment.
Income Tax Expense increased for the six month period due primarily to higher pre-tax earnings ($92.7 million), higher state taxes ($29.6 million), a higher share-based payment tax deficiency ($1.9 million), and a decrease in amortization of EDIT ($10.0 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 ($0.5 million) and a decrease in reserves ($42.9 million) primarily related to the 2023 impairment of Eversource’s offshore wind investment.
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 months ended June 30, 2024 and 2023 included in this combined Quarterly Report on Form 10-Q:

| For the Six Months Ended June 30,
| CL&P |  | NSTAR Electric |  | PSNH
(Millions of Dollars) | 2024 |  | 2023 |  | Increase/ (Decrease) |  | 2024 |  | 2023 |  | Increase/ (Decrease) |  | 2024 |  | 2023 |  | Increase/ (Decrease)
Operating Revenues | $ | 2,085.9 |  |  | $ | 2,373.1 |  |  | $ | (287.2) |  |  | $ | 1,792.7 |  |  | $ | 1,775.3 |  |  | $ | 17.4 |  |  | $ | 613.4 |  |  | $ | 770.2 |  |  | $ | (156.8) |
Operating Expenses: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Purchased Power and Transmission | 1,046.4 |  |  | 1,477.0 |  |  | (430.6) |  |  | 482.7 |  |  | 627.5 |  |  | (144.8) |  |  | 124.9 |  |  | 371.5 |  |  | (246.6) |
Operations and Maintenance | 384.2 |  |  | 326.9 |  |  | 57.3 |  |  | 337.3 |  |  | 312.9 |  |  | 24.4 |  |  | 138.4 |  |  | 132.3 |  |  | 6.1 |
Depreciation | 198.9 |  |  | 185.9 |  |  | 13.0 |  |  | 197.2 |  |  | 183.3 |  |  | 13.9 |  |  | 75.5 |  |  | 68.8 |  |  | 6.7 |
Amortization of Regulatory (Liabilities)/Assets, Net | (246.7) |  |  | (312.2) |  |  | 65.5 |  |  | 69.6 |  |  | 21.4 |  |  | 48.2 |  |  | 50.0 |  |  | (25.3) |  |  | 75.3 |
Energy Efficiency Programs | 67.1 |  |  | 60.8 |  |  | 6.3 |  |  | 149.0 |  |  | 156.9 |  |  | (7.9) |  |  | 20.9 |  |  | 19.4 |  |  | 1.5 |
Taxes Other Than Income Taxes | 200.2 |  |  | 196.1 |  |  | 4.1 |  |  | 131.0 |  |  | 119.8 |  |  | 11.2 |  |  | 47.8 |  |  | 47.6 |  |  | 0.2 |
Total Operating Expenses | 1,650.1 |  |  | 1,934.5 |  |  | (284.4) |  |  | 1,366.8 |  |  | 1,421.8 |  |  | (55.0) |  |  | 457.5 |  |  | 614.3 |  |  | (156.8) |
Operating Income | 435.8 |  |  | 438.6 |  |  | (2.8) |  |  | 425.9 |  |  | 353.5 |  |  | 72.4 |  |  | 155.9 |  |  | 155.9 |  |  | — |
Interest Expense | 116.6 |  |  | 93.0 |  |  | 23.6 |  |  | 104.1 |  |  | 91.6 |  |  | 12.5 |  |  | 39.4 |  |  | 36.6 |  |  | 2.8 |
Other Income, Net | 39.4 |  |  | 28.3 |  |  | 11.1 |  |  | 95.5 |  |  | 80.8 |  |  | 14.7 |  |  | 14.8 |  |  | 12.0 |  |  | 2.8 |
Income Before Income Tax Expense | 358.6 |  |  | 373.9 |  |  | (15.3) |  |  | 417.3 |  |  | 342.7 |  |  | 74.6 |  |  | 131.3 |  |  | 131.3 |  |  | — |
Income Tax Expense | 88.6 |  |  | 92.2 |  |  | (3.6) |  |  | 99.7 |  |  | 74.1 |  |  | 25.6 |  |  | 31.5 |  |  | 30.6 |  |  | 0.9 |
Net Income | $ | 270.0 |  |  | $ | 281.7 |  |  | $ | (11.7) |  |  | $ | 317.6 |  |  | $ | 268.6 |  |  | $ | 49.0 |  |  | $ | 99.8 |  |  | $ | 100.7 |  |  | $ | (0.9) |

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

| For the Six Months Ended June 30,
| 2024 |  | 2023 |  |  |  | Percentage Increase
CL&P | 9,732 |  |  | 9,138 |  |  |  |  | 6.5 | %
NSTAR Electric | 10,907 |  |  | 10,579 |  |  |  |  | 3.1 | %
PSNH | 3,784 |  |  | 3,645 |  |  |  |  | 3.8 | %

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, decreased $287.2 million at CL&P and $156.8 million at PSNH, and increased $17.4 million at NSTAR Electric for the six month period.
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Base Distribution Revenues:
•CL&P's distribution revenues were flat for the six month period.
•NSTAR Electric's distribution revenues increased $49.8 million for the six month period due primarily to a base distribution rate increase effective January 1, 2024.
•PSNH's distribution revenues increased $6.8 million for the six month period due primarily to an increase in sales volumes in 2024 compared to 2023.
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. 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. 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. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties.
Customers have the choice to purchase electricity from their 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 utility 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 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.
The variance in tracked distribution revenues for the six month period is due primarily to the following:

(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH
Retail Tariff Tracked Revenues: |  |  |  |  |
Energy supply procurement | $ | (469.4) |  |  | $ | (181.9) |  |  | $ | (204.3) |
CL&P FMCC | 157.9 |  |  | — |  |  | — |
Retail transmission | 45.4 |  |  | 22.2 |  |  | 23.5 |
Net Metering | — |  |  | 59.5 |  |  | — |
Other distribution tracking mechanisms | (10.7) |  |  | 81.6 |  |  | 33.0 |
Wholesale Market Sales Revenue | 1.0 |  |  | (15.0) |  |  | (18.3) |

The decrease in energy supply procurement at CL&P, NSTAR Electric and PSNH for the six month period was driven by lower average prices and lower average supply-related sales volumes.
The increase in CL&P’s FMCC revenues was driven by an increase in the retail Non-Bypassable Federally Mandated Congestion Charge (NBFMCC) rate. The CL&P NBFMCC rate includes the recovery of costs incurred under long-term state approved energy contracts with the Millstone and Seabrook nuclear power plants, net of the benefits received from selling this energy into the ISO-NE wholesale market. Effective January 1, 2023, CL&P reduced the average NBFMCC rate to a credit of $0.01524 per kWh. The rate reduction returned to customers the net benefits of higher wholesale market sales received in the ISO-NE market for these energy contracts. The average NBFMCC rate changed to $0.00000 per kWh effective July 1, 2023 and then to $0.00293 per kWh effective September 1, 2023. As a result of the April 2024 interim decision in the 2024 CL&P RAM filing, the average NBFMCC rate increased to $0.03906 per kWh effective July 1, 2024. As a result of the July 2024 draft final decision in the 2024 CL&P RAM filing, the average NBFMCC will increase to $0.04279 per kWh effective September 1, 2024. The rate increases primarily resulted from higher costs associated with power purchase agreements with the Millstone and Seabrook nuclear power plants.
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.
Transmission Revenues: Transmission revenues increased $36.1 million at CL&P, $46.3 million at NSTAR Electric, and $20.7 million at PSNH for the six month period, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure and the impact of the annual billing and cost reconciliation filing with FERC.
Eliminations: Eliminations are primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business in rates charged to their customers. The impact of eliminations decreased revenues by $47.7 million at CL&P, $46.0 million at NSTAR Electric, and $21.3 million at PSNH for the six month period.
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Purchased Power and Transmission expense includes costs associated with providing electric generation service supply to all customers who have not migrated to third party suppliers, the cost of energy purchase contracts entered into as required by regulation, and transmission costs. These energy supply procurement costs, other energy-related costs, and transmission costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). The variance in Purchased Power and Transmission expense is due primarily to the following:

(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH
Energy supply procurement costs | $ | (470.8) |  |  | $ | (181.2) |  |  | $ | (203.7) |
Other electric distribution costs | 57.9 |  |  | 59.9 |  |  | (38.1) |
Transmission costs | 30.0 |  |  | 22.5 |  |  | 16.5 |
Eliminations | (47.7) |  |  | (46.0) |  |  | (21.3) |
Total Purchased Power and Transmission | $ | (430.6) |  |  | $ | (144.8) |  |  | $ | (246.6) |

The variance in energy supply procurement costs is offset in Operating Revenues (tracked energy supply procurement revenues). The variance in other electric distribution costs at NSTAR Electric is due to an increase in net metering costs, at CL&P is due to higher long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism, and at PSNH is due to a decrease in long-term renewable energy purchase contract 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 in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network. This was partially offset by a decrease resulting from the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers.
Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). The variance in Operations and Maintenance expense is due primarily to the following:

(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH
Base Electric Distribution (Non-Tracked Costs): |  |  |  |  |
Storm costs | $ | 11.2 |  |  | $ | 6.3 |  |  | $ | (1.2) |
Vegetation management | 8.7 |  |  | (1.9) |  |  | (1.8) |
Employee-related expenses (including labor and benefits) | 8.3 |  |  | (4.7) |  |  | 1.2 |
General costs (including vendor services in corporate areas, uncollectible expense, insurance, fees and assessments) and other operations-related expenses | 3.4 |  |  | 4.9 |  |  | (0.5) |
Shared corporate costs (including IT system depreciation at Eversource Service) | 3.2 |  |  | 2.4 |  |  | 1.1 |
Total Base Electric Distribution (Non-Tracked Costs) | 34.8 |  |  | 7.0 |  |  | (1.2) |
Total Tracked Costs - Increase due primarily to higher transmission expense | 22.5 |  |  | 17.4 |  |  | 7.3 |
Total Operations and Maintenance | $ | 57.3 |  |  | $ | 24.4 |  |  | $ | 6.1 |

Depreciation expense increased f or the six month period for CL&P, NSTAR Electric and PSNH due to higher net plant in service balances.
Amortization of Regulatory (Liabilities)/Assets, Net expense includes the deferral of energy-related costs and other costs that are included in certain regulatory commission-approved cost tracking mechanisms. This deferral adjusts expense to match the corresponding revenues compared to the actual costs incurred. These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of certain costs as those costs are collected in rates. The variance in Amortization of Regulatory (Liabilities)/Assets, Net for the six month period is due primarily to the following:
•The variance at CL&P was due primarily to the deferral adjustment of energy-related and other tracked costs that are included in the non-bypassable component of the FMCC mechanism, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The CL&P non-bypassable FMCC retail rate increased in the six month period, and the higher collections lowered the regulatory under-recovery deferral adjustment recorded in the same period, resulting in an increase to amortization expense of $116.3 million.
•The increase in expense at NSTAR Electric was due to the deferral adjustment of energy-related and other tracked costs that are included in the transition and solar facilities regulatory mechanisms, and higher amortization of storm costs recovered in rates.
•The increase in expense at PSNH was due to the deferral adjustment of energy-related and other tracked costs that are included in the stranded cost recovery charge regulatory mechanism and the absence of a second quarter 2023 benefit related to the establishment of a new regulatory tracking mechanism that allowed for the recovery of previously incurred operating expenses associated with poles acquired from Consolidated Communications on May 1, 2023. The establishment of the PPAM regulatory asset resulted in a pre-tax benefit of $16.9 million recorded in Amortization expense on the PSNH statement of income in the second quarter of 2023.
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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 includes a deferral adjustment that reflects the actual costs of energy efficiency programs compared to the amounts billed to customers, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The variance in Energy Efficiency Programs expense for the six month period is due primarily to the following:
•The increase at CL&P was due to the deferral adjustment, partially offset by lower program spending.
•The decrease at NSTAR Electric was due to the deferral adjustment, partially offset by higher program spending.
•The increase at PSNH was due to higher program spending, partially offset by the deferral adjustment.
Taxes Other Than Income Taxes - the variance is due primarily to the following:
•The increase at CL&P was due primarily to higher property taxes as a result of higher utility plant balances.
•The increase at NSTAR Electric was due primarily to higher property taxes as a result of higher utility plant balances and higher assessments.
Interest Expense - the variance is due primarily to the following:
•The increase at CL&P was due to higher interest on long-term debt as a result of new debt issuances ($14.7 million), higher interest on short-term notes payable due to increased borrowings ($4.9 million), an increase in interest expense on regulatory deferrals ($4.1 million), and higher amortization of debt discounts and premiums, net ($0.4 million), partially offset by an increase in capitalized AFUDC related to debt funds ($0.7 million).
•The increase at NSTAR Electric was due to an increase in interest expense on regulatory deferrals ($7.3 million), higher interest on long-term debt as a result of new debt issuances ($6.2 million), and higher interest on short-term notes payable due to increased borrowings ($5.6 million), partially offset by an increase in capitalized AFUDC related to debt funds ($6.9 million).
•The increase at PSNH was due to higher interest on long-term debt as a result of new debt issuances ($6.8 million) and higher interest on short-term notes payable ($0.6 million), partially offset by an increase in capitalized AFUDC related to debt funds ($2.9 million), a decrease in interest expense on regulatory deferrals ($0.8 million), a decrease i n RRB interest expense ($0.7 million) and lower amortization of debt discounts and premiums, net ($0.3 million).
Other Income, Net - the variance is due primarily to the following:
•The increase at CL&P was due primarily to an increase in interest income primarily on regulatory deferrals ($11.7 million), an increase in capitalized AFUDC related to equity funds ($2.8 million) and lower investment losses driven by market volatility ($0.8 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($4.2 million).
•The increase at NSTAR Electric was due primarily to an increase in capitalized AFUDC related to equity funds ($9.9 million), an increase in interest income primarily on regulatory deferrals ($6.8 million) and investment income in 2024 compared to investment loss in 2023 driven by market volatility ($1.1 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($3.2 million).
•The increase at PSNH was due primarily to an increase in interest income primarily on regulatory deferrals ($2.0 million) and an increase in capitalized AFUDC related to equity funds ($1.8 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($0.8 million).
Income Tax Expense - the variance is due primarily to the following:
•The decrease at CL&P was due primarily to lower pre-tax earnings ($3.2 million), lower state taxes ($2.2 million), and a decrease in valuation allowances ($2.8 million), partially offset by a higher share-based payment tax deficiency ($0.6 million), a decrease in amortization of EDIT ($1.3 million) and an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($2.7 million).
•The increase at NSTAR Electric was due primarily to higher pre-tax earnings ($15.7 million), higher state taxes ($4.4 million), a higher share-based payment tax deficiency ($0.6 million), and a decrease in amortization of EDIT ($7.0 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 ($2.1 million).
•The increase at PSNH was due primarily to higher pre-tax earnings ($0.1 million), and a decrease in amortization of EDIT ($1.0 million), partially offset by lower state taxes ($0.1 million), and a decrease in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.1 million).
EARNINGS SUMMARY
CL&P's earnings decreased $11.7 million for the six month period due primarily to higher operations and maintenance expense, higher interest expense, and higher depreciation expense, partially offset by an increase in transmission earnings driven primarily by a higher transmission rate base, higher revenues from its capital tracking mechanism due to increased electric system improvements, and an increase in interest income primarily on regulatory deferrals.
NSTAR Electric's earnings increased $49.0 million for the six month period due primarily to higher revenues as a result of the base distribution rate increase effective January 1, 2024, an increase in transmission earnings driven primarily by a higher transmission rate base, an increase in
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interest income primarily on regulatory deferrals, and higher AFUDC equity income. The earnings increase was partially offset by higher interest expense, higher property tax expense, higher operations and maintenance expense, and higher depreciation expense.
PSNH's earnings decreased $0.9 million for the six month period due primarily to the absence of a prior year benefit related to the establishment of a new regulatory tracking mechanism that allowed for the recovery of previously incurred operating expenses associated with poles acquired on May 1, 2023, higher depreciation expense, and higher interest expense. The earnings decrease was partially offset by an increase in transmission earnings driven primarily by a higher transmission rate base, and higher base distribution revenues driven by an increase in sales volumes.
LIQUIDITY
Cash Flows: CL&P had cash flows provided by operating activities of $109.8 million for the six months ended June 30, 2024, as compared to $129.0 million in the same period of 2023. The decrease in operating cash flows was due primarily to an increase in regulatory under-recoveries driven primarily by the timing of collections for energy supply costs, costs included in the SBC and other regulatory tracking mechanisms, the timing of cash collections on our accounts receivable, and the timing of other working capital items. The impacts of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Liabilities, Net on the statements of cash flows. These unfavorable impacts were partially offset by the timing of cash payments made on our accounts payable, a $40.1 million decrease in cash payments to vendors for storm costs, and a decrease in cost of removal expenditures.
NSTAR Electric had cash flows provided by operating activities of $341.4 million for the six months ended June 30, 2024, as compared to $233.5 million in the same period of 2023. The increase in operating cash flows was due primarily to a decrease in regulatory under-recoveries driven primarily by the timing of collections for net metering costs, solar costs and other regulatory tracking mechanisms, a decrease in cost of removal expenditures, and the timing of other working capital items. The impacts of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Assets, Net on the statements of cash flows. These favorable impacts were partially offset by a $72.2 million decrease in operating cash flows due to income tax payments made in 2024 compared to income tax refunds received in 2023, a $35.4 million increase in cash payments to vendors for storm costs, the timing of cash collections on our accounts receivable, and the timing of cash payments made on our accounts payable.
PSNH had cash flows provided by operating activities of $76.5 million for the six months ended June 30, 2024, as compared to cash flows used in operating activities of $92.6 million in the same period of 2023. The increase in operating cash flows was due primarily to a decrease in regulatory under-recoveries driven primarily by the timing of collections for energy supply costs, stranded costs and other regulatory tracking mechanisms, the timing of cash payments made on our accounts payable, a $37.9 million decrease in cash payments to vendors for storm costs, and the timing of other working capital items. The impacts of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Assets/(Liabilities), Net on the statements of cash flows. These favorable impacts were partially offset by a $41.5 million decrease in income tax refunds received in 2024 compared to 2023, the timing of cash collections on our accounts receivable, and an increase in cost of removal expenditures.
For further information on CL&P's, NSTAR Electric's and PSNH's liquidity and capital resources, see "Liquidity" and "Business Development and Capital Expenditures" included in this Management's Discussion and Analysis of Financial Condition and Results of Operations.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Market Risk Information
Commodity Price Risk Management: Our regulated companies enter into energy contracts to serve our customers, and the economic impacts of those contracts are passed on to our customers. Accordingly, the regulated companies have no exposure to loss of future earnings or fair values due to these market risk-sensitive instruments. Eversource's Energy Supply Risk Committee, comprised of senior officers, reviews and approves all large-scale energy related transactions entered into by its regulated companies.
Other Risk Management Activities
Interest Rate Risk Management: Interest rate risk is associated with changes in interest rates for our outstanding long-term debt. Our interest rate risk is significantly reduced as typically all or most of our debt financings have fixed interest rates. As of June 30, 2024, all of our long-term debt was at a fixed interest rate.
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 c ontracting risks, including credit risk. As of June 30, 2024, our regulated companies held collateral (letters of credit or cash) of $5.5 million from counterparties related to our standard service contracts. As of June 30, 2024, Eversource had $14.5 million of cash pos ted with ISO-NE related to energy transactions.
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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 2023 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 2023 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, 2024 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, 2024 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
We are parties to various legal proceedings. We have disclosed certain legal proceedings in Part I, Item 3, "Legal Proceedings," and elsewhere in our 2023 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 2023 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 2023 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 2023 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, 2024 | 3,243 |  | $ | 58.65 |  | — |  | — |
May 1 - May 31, 2024 | — |  | — |  | — |  | — |
June 1 - June 30, 2024 | 3,421 |  | 56.63 |  | — |  | — |
Total | 6,664 |  | $ | 57.61 |  | — |  | — |

ITEM 3. DEFAULTS UPON SENIOR SECURITIES
Not applicable.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
ITEM 5. OTHER INFORMATION
During the quarter ended June 30, 2024, none of the Company’s directors or officers adopted, modified, or terminated a “Rule 10b5-1 trading arrangement” or a “non-Rule 10b5-1 trading arrangement,” as such terms are defined under Item 408 of Regulation S-K.
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ITEM 6. EXHIBITS
Each document described below is filed herewith, unless designated with an asterisk (*), which exhibits are incorporated by reference by the registrant under whose name the exhibit appears.

| Exhibit No. | Description
| Listing of Exhibits (Eversource)
| 31 | Certification by the Chairman of the Board, President and 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 Chairman of the Board, President and 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 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 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 5.40% Debenture due 2034 (Exhibit 4.1, NSTAR Electric Company Current Report on Form 8-K filed on May 22, 2024, 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, 2024, formatted in Inline XBRL

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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 2, 2024 |  | By: | /s/ Jay S. Buth
|  |  | Jay S. Buth
|  |  | Vice President, Controller and Chief Accounting Officer

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

|  | THE CONNECTICUT LIGHT AND POWER COMPANY
August 2, 2024 |  | By: | /s/ Jay S. Buth
|  |  | Jay S. Buth
|  |  | Vice President, Controller and Chief Accounting Officer

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

|  | NSTAR ELECTRIC COMPANY
August 2, 2024 |  | By: | /s/ Jay S. Buth
|  |  | Jay S. Buth
|  |  | Vice President, Controller and Chief Accounting Officer

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

|  | PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
August 2, 2024 |  | By: | /s/ Jay S. Buth
|  |  | Jay S. Buth
|  |  | Vice President, Controller and Chief Accounting Officer

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