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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 | September 30, 2023
| or
☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
| For the transition period from ____________ to ____________

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

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

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

| Yes | No
| ☒ | ☐

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

| Yes | No
| ☒ | ☐

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

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

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

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

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

Company - Class of Stock | Outstanding as of October 31, 2023
Eversource Energy Common Shares, $5.00 par value | 349,326,209 |  | shares
The Connecticut Light and Power Company Common Stock, $10.00 par value | 6,035,205 |  | shares
NSTAR Electric Company Common Stock, $1.00 par value | 200 |  | shares
Public Service Company of New Hampshire Common Stock, $1.00 par value | 301 |  | shares

Eversource Energy holds all of the 6,035,205 shares, 200 shares, and 301 shares of the outstanding common stock of The Connecticut Light and Power Company, NSTAR Electric Company, and Public Service Company of New Hampshire, respectively.
NSTAR Electric Company and Public Service Company of New Hampshire each meet the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q, and each is therefore filing this Form 10-Q with the reduced disclosure format specified in General Instruction H(2) of Form 10‑Q.
Eversource Energy, The Connecticut Light and Power Company, NSTAR Electric Company, and Public Service Company of New Hampshire each separately file this combined Form 10-Q. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. Each registrant makes no representation as to information relating to the other registrants.

GLOSSARY OF TERMS
The following is a glossary of abbreviations and acronyms that are found in this report:

Current or former Eversource Energy companies, segments or investments:
Eversource, ES or the Company | Eversource Energy and subsidiaries
Eversource parent or ES parent | Eversource Energy, a public utility holding company
ES parent and other companies | ES parent and other companies are comprised of Eversource parent, Eversource Service, and other subsidiaries, which primarily includes our unregulated businesses, HWP Company, The Rocky River Realty Company (a real estate subsidiary), the consolidated operations of CYAPC and YAEC, and Eversource parent's equity ownership interests that are not consolidated
CL&P | The Connecticut Light and Power Company
NSTAR Electric | NSTAR Electric Company
PSNH | Public Service Company of New Hampshire
PSNH Funding | PSNH Funding LLC 3, a bankruptcy remote, special purpose, wholly-owned subsidiary of PSNH
NSTAR Gas | NSTAR Gas Company
EGMA | Eversource Gas Company of Massachusetts
Yankee Gas | Yankee Gas Services Company
Aquarion | Aquarion Company and its subsidiaries
HEEC | Harbor Electric Energy Company, a wholly-owned subsidiary of NSTAR Electric
Eversource Service | Eversource Energy Service Company
North East Offshore | North East Offshore, LLC, an offshore wind business being developed jointly by Eversource and Denmark-based Ørsted
CYAPC | Connecticut Yankee Atomic Power Company
MYAPC | Maine Yankee Atomic Power Company
YAEC | Yankee Atomic Electric Company
Yankee Companies | CYAPC, YAEC and MYAPC
Regulated companies | The Eversource regulated companies are comprised of the electric distribution and transmission businesses of CL&P, NSTAR Electric and PSNH, the natural gas distribution businesses of Yankee Gas, NSTAR Gas and EGMA, Aquarion’s water distribution businesses, and the solar power facilities of NSTAR Electric
Regulators and Government Agencies:
BOEM | U.S. Bureau of Ocean Energy Management
DEEP | Connecticut Department of Energy and Environmental Protection
DOE | U.S. Department of Energy
DOER | Massachusetts Department of Energy Resources
DPU | Massachusetts Department of Public Utilities
EPA | U.S. Environmental Protection Agency
FERC | Federal Energy Regulatory Commission
ISO-NE | ISO New England, Inc., the New England Independent System Operator
MA DEP | Massachusetts Department of Environmental Protection
NHPUC | New Hampshire Public Utilities Commission
PURA | Connecticut Public Utilities Regulatory Authority
SEC | U.S. Securities and Exchange Commission
Other Terms and Abbreviations:
ADIT | Accumulated Deferred Income Taxes
AFUDC | Allowance For Funds Used During Construction
AOCI | Accumulated Other Comprehensive Income
ARO | Asset Retirement Obligation
Bcf | Billion cubic feet
CfD | Contract for Differences
CWIP | Construction Work in Progress
EDC | Electric distribution company
EDIT | Excess Deferred Income Taxes
EPS | Earnings Per Share
ERISA | Employee Retirement Income Security Act of 1974
ESOP | Employee Stock Ownership Plan
Eversource 2022 Form 10-K | The Eversource Energy and Subsidiaries 2022 combined Annual Report on Form 10-K as filed with the SEC
Fitch | Fitch Ratings, Inc.

i

FMCC | Federally Mandated Congestion Charge
GAAP | Accounting principles generally accepted in the United States of America
GWh | Gigawatt-Hours
IPP | Independent Power Producers
ISO-NE Tariff | ISO-NE FERC Transmission, Markets and Services Tariff
kV | Kilovolt
kVa | Kilovolt-ampere
kW | Kilowatt (equal to one thousand watts)
LNG | Liquefied natural gas
LPG | Liquefied petroleum gas
LRS | Supplier of last resort service
MG | Million gallons
MGP | Manufactured Gas Plant
MMBtu | Million British thermal units
MMcf | Million cubic feet
Moody's | Moody's Investors Services, Inc.
MW | Megawatt
MWh | Megawatt-Hours
NETOs | New England Transmission Owners (including Eversource, National Grid and Avangrid)
OCI | Other Comprehensive Income/(Loss)
PAM | Pension and PBOP Rate Adjustment Mechanism
PBOP | Postretirement Benefits Other Than Pension
PBOP Plan | Postretirement Benefits Other Than Pension Plan
Pension Plan | Single uniform noncontributory defined benefit retirement plan
PPA | Power purchase agreement
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 | 5
| The Connecticut Light and Power Company (Unaudited) |
| Condensed Balance Sheets | 6
| Condensed Statements of Income | 7
| Condensed Statements of Comprehensive Income | 7
| Condensed Statements of Common Stockholder's Equity | 8
| Condensed Statements of Cash Flows | 9
| NSTAR Electric Company and Subsidiary (Unaudited) |
| Condensed Consolidated Balance Sheets | 10
| Condensed Consolidated Statements of Income | 11
| Condensed Consolidated Statements of Comprehensive Income | 11
| Condensed Consolidated Statements of Common Stockholder's Equity | 12
| Condensed Consolidated Statements of Cash Flows | 13
| Public Service Company of New Hampshire and Subsidiaries (Unaudited) |
| Condensed Consolidated Balance Sheets | 14
| Condensed Consolidated Statements of Income | 15
| Condensed Consolidated Statements of Comprehensive Income | 15
| Condensed Consolidated Statements of Common Stockholder's Equity | 16
| Condensed Consolidated Statements of Cash Flows | 17
| Combined Notes to Condensed Financial Statements (Unaudited) | 18
ITEM 2. | Management's Discussion and Analysis of Financial Condition and Results of Operations |
| Eversource Energy and Subsidiaries | 40
| The Connecticut Light and Power Company, NSTAR Electric Company and Subsidiary, and Public Service Company of New Hampshire and Subsidiaries | 58
ITEM 3. | Quantitative and Qualitative Disclosures About Market Risk | 65
ITEM 4. | Controls and Procedures | 65
PART II – OTHER INFORMATION
ITEM 1. | Legal Proceedings | 66
ITEM 1A. | Risk Factors | 66
ITEM 2. | Unregistered Sales of Equity Securities and Use of Proceeds | 66
ITEM 3. | Defaults Upon Senior Securities | 66
ITEM 4. | Mine Safety Disclosures | 66
ITEM 5. | Other Information | 66
ITEM 6. | Exhibits | 67
SIGNATURES | 68

iii

EVERSOURCE ENERGY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)

(Thousands of Dollars) | As of September 30, 2023 |  | As of December 31, 2022
ASSETS |  |  |
Current Assets: |  |  |
Cash | $ | 78,813 |  |  | $ | 47,597 |
Cash Equivalents | — |  |  | 327,006 |
Receivables, Net (net of allowance for uncollectible accounts of $542,746 and $486,297 as of September 30, 2023 and December 31, 2022, respectively) | 1,430,183 |  |  | 1,517,138 |
Unbilled Revenues | 171,934 |  |  | 238,968 |
Materials, Supplies, Natural Gas and REC Inventory | 445,810 |  |  | 374,395 |
Regulatory Assets | 1,507,888 |  |  | 1,335,491 |
Prepayments and Other Current Assets | 374,471 |  |  | 382,603 |
Total Current Assets | 4,009,099 |  |  | 4,223,198 |
Property, Plant and Equipment, Net | 38,518,294 |  |  | 36,112,820 |
Deferred Debits and Other Assets: |  |  |
Regulatory Assets | 4,348,700 |  |  | 4,242,794 |
Goodwill | 4,530,121 |  |  | 4,522,632 |
Investments in Unconsolidated Affiliates | 2,723,931 |  |  | 2,176,080 |
Prepaid Pension and PBOP | 1,238,512 |  |  | 1,045,524 |
Marketable Securities | 327,381 |  |  | 366,508 |
Other Long-Term Assets | 597,305 |  |  | 541,344 |
Total Deferred Debits and Other Assets | 13,765,950 |  |  | 12,894,882 |
Total Assets | $ | 56,293,343 |  |  | $ | 53,230,900 |
LIABILITIES AND CAPITALIZATION |  |  |
Current Liabilities: |  |  |
Notes Payable | $ | 1,529,800 |  |  | $ | 1,442,200 |
Long-Term Debt – Current Portion | 2,071,862 |  |  | 1,320,129 |
Rate Reduction Bonds – Current Portion | 43,210 |  |  | 43,210 |
Accounts Payable | 1,642,181 |  |  | 2,113,905 |
Regulatory Liabilities | 724,413 |  |  | 890,786 |
Other Current Liabilities | 1,108,178 |  |  | 989,053 |
Total Current Liabilities | 7,119,644 |  |  | 6,799,283 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated Deferred Income Taxes | 5,238,623 |  |  | 5,067,902 |
Regulatory Liabilities | 4,021,830 |  |  | 3,930,305 |
Derivative Liabilities | 85,322 |  |  | 143,929 |
Asset Retirement Obligations | 504,671 |  |  | 502,713 |
Accrued Pension, SERP and PBOP | 118,462 |  |  | 135,473 |
Other Long-Term Liabilities | 908,731 |  |  | 888,081 |
Total Deferred Credits and Other Liabilities | 10,877,639 |  |  | 10,668,403 |
Long-Term Debt | 22,087,267 |  |  | 19,723,994 |
Rate Reduction Bonds | 367,282 |  |  | 410,492 |
Noncontrolling Interest – Preferred Stock of Subsidiaries | 155,570 |  |  | 155,570 |
Common Shareholders' Equity: |  |  |
Common Shares | 1,799,920 |  |  | 1,799,920 |
Capital Surplus, Paid In | 8,443,820 |  |  | 8,401,731 |
Retained Earnings | 5,666,861 |  |  | 5,527,153 |
Accumulated Other Comprehensive Loss | (24,022) |  |  | (39,421) |
Treasury Stock | (200,638) |  |  | (216,225) |
Common Shareholders' Equity | 15,685,941 |  |  | 15,473,158 |
Commitments and Contingencies (Note 9) |  |  |
Total Liabilities and Capitalization | $ | 56,293,343 |  |  | $ | 53,230,900 |

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

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

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Thousands of Dollars, Except Share Information) | 2023 |  | 2022 |  | 2023 |  | 2022
Operating Revenues | $ | 2,791,482 |  |  | $ | 3,215,645 |  |  | $ | 9,216,467 |  |  | $ | 9,259,596 |
Operating Expenses: |  |  |  |  |  |  |
Purchased Power, Purchased Natural Gas and Transmission | 1,168,599 |  |  | 1,388,041 |  |  | 4,232,912 |  |  | 3,718,278 |
Operations and Maintenance | 500,711 |  |  | 454,289 |  |  | 1,382,563 |  |  | 1,378,897 |
Depreciation | 329,528 |  |  | 302,143 |  |  | 962,477 |  |  | 885,711 |
Amortization | (143,979) |  |  | 111,287 |  |  | (438,460) |  |  | 418,644 |
Energy Efficiency Programs | 162,425 |  |  | 162,545 |  |  | 531,199 |  |  | 498,708 |
Taxes Other Than Income Taxes | 243,645 |  |  | 240,047 |  |  | 704,989 |  |  | 683,441 |
Total Operating Expenses | 2,260,929 |  |  | 2,658,352 |  |  | 7,375,680 |  |  | 7,583,679 |
Operating Income | 530,553 |  |  | 557,293 |  |  | 1,840,787 |  |  | 1,675,917 |
Interest Expense | 222,283 |  |  | 178,174 |  |  | 624,140 |  |  | 491,509 |
Impairment of Offshore Wind Investment | — |  |  | — |  |  | 401,000 |  |  | — |
Other Income, Net | 79,123 |  |  | 89,831 |  |  | 262,980 |  |  | 255,253 |
Income Before Income Tax Expense | 387,393 |  |  | 468,950 |  |  | 1,078,627 |  |  | 1,439,661 |
Income Tax Expense | 45,850 |  |  | 117,661 |  |  | 226,743 |  |  | 349,305 |
Net Income | 341,543 |  |  | 351,289 |  |  | 851,884 |  |  | 1,090,356 |
Net Income Attributable to Noncontrolling Interests | 1,880 |  |  | 1,880 |  |  | 5,639 |  |  | 5,639 |
Net Income Attributable to Common Shareholders | $ | 339,663 |  |  | $ | 349,409 |  |  | $ | 846,245 |  |  | $ | 1,084,717 |
Basic Earnings Per Common Share | $ | 0.97 |  |  | $ | 1.01 |  |  | $ | 2.42 |  |  | $ | 3.13 |
Diluted Earnings Per Common Share | $ | 0.97 |  |  | $ | 1.00 |  |  | $ | 2.42 |  |  | $ | 3.13 |
Weighted Average Common Shares Outstanding: |  |  |  |  |  |  |
Basic | 349,704,155 |  |  | 347,297,411 |  |  | 349,461,219 |  |  | 346,115,823 |
Diluted | 349,851,969 |  |  | 347,762,693 |  |  | 349,731,320 |  |  | 346,573,101 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022 |  | 2023 |  | 2022
Net Income | $ | 341,543 |  |  | $ | 351,289 |  |  | $ | 851,884 |  |  | $ | 1,090,356 |
Other Comprehensive Income, Net of Tax: |  |  |  |  |  |  |
Qualified Cash Flow Hedging Instruments | 5 |  |  | 5 |  |  | 15 |  |  | 15 |
Changes in Unrealized (Losses)/Gains on Marketable Securities | — |  |  | (667) |  |  | 1,254 |  |  | (1,990) |
Changes in Funded Status of Pension, SERP and PBOP Benefit Plans | 8,076 |  |  | 2,520 |  |  | 14,130 |  |  | 3,244 |
Other Comprehensive Income, Net of Tax | 8,081 |  |  | 1,858 |  |  | 15,399 |  |  | 1,269 |
Comprehensive Income Attributable to Noncontrolling Interests | (1,880) |  |  | (1,880) |  |  | (5,639) |  |  | (5,639) |
Comprehensive Income Attributable to Common Shareholders | $ | 347,744 |  |  | $ | 351,267 |  |  | $ | 861,644 |  |  | $ | 1,085,986 |

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 Nine Months Ended September 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 |
Net Income |  |  |  | 341,543 |  |  |  | 341,543 |
Dividends on Common Shares - $0.675 Per Share |  |  |  | (235,691) |  |  |  | (235,691) |
Dividends on Preferred Stock |  |  |  | (1,880) |  |  |  | (1,880) |
Long-Term Incentive Plan Activity |  |  | 3,075 |  |  |  |  | 3,075 |
Issuance of Treasury Shares | 253,839 |  |  | 11,959 |  |  |  | 4,756 |  | 16,715 |
Other Comprehensive Income |  |  |  |  | 8,081 |  |  | 8,081 |
Balance as of September 30, 2023 | 349,275,775 |  | $ | 1,799,920 |  | $ | 8,443,820 |  | $ | 5,666,861 |  | $ | (24,022) |  | $ | (200,638) |  | $ | 15,685,941 |

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

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

| For the Nine Months Ended September 30, 2022
| Common Shares | Capital Surplus, Paid In | Retained Earnings | Accumulated Other Comprehensive Loss | Treasury Stock | Total Common Shareholders' Equity
(Thousands of Dollars, Except Share Information) | Shares | Amount
Balance as of January 1, 2022 | 344,403,196 |  | $ | 1,789,092 |  | $ | 8,098,514 |  | $ | 5,005,391 |  | $ | (42,275) |  | $ | (250,878) |  | $ | 14,599,844 |
Net Income |  |  |  | 445,326 |  |  |  | 445,326 |
Dividends on Common Shares - $0.6375 Per Share |  |  |  | (219,768) |  |  |  | (219,768) |
Dividends on Preferred Stock |  |  |  | (1,880) |  |  |  | (1,880) |
Long-Term Incentive Plan Activity |  |  | (16,538) |  |  |  |  | (16,538) |
Issuance of Treasury Shares | 447,076 |  |  | 20,642 |  |  |  | 8,360 |  | 29,002 |
Other Comprehensive Income |  |  |  |  | 704 |  |  | 704 |
Balance as of March 31, 2022 | 344,850,272 |  | 1,789,092 |  | 8,102,618 |  | 5,229,069 |  | (41,571) |  | (242,518) |  | 14,836,690 |
Net Income |  |  |  | 293,742 |  |  |  | 293,742 |
Dividends on Common Shares - $0.6375 Per Share |  |  |  | (219,877) |  |  |  | (219,877) |
Dividends on Preferred Stock |  |  |  | (1,880) |  |  |  | (1,880) |
Issuance of Common Shares - $5 par value | 1,392,804 |  | 6,964 |  | 121,142 |  |  |  |  | 128,106 |
Long-Term Incentive Plan Activity |  |  | 9,070 |  |  |  |  | 9,070 |
Issuance of Treasury Shares | 167,953 |  |  | 11,340 |  |  |  | 3,141 |  | 14,481 |
Capital Stock Expense |  |  | (1,824) |  |  |  |  | (1,824) |
Other Comprehensive Loss |  |  |  |  | (1,293) |  |  | (1,293) |
Balance as of June 30, 2022 | 346,411,029 |  | 1,796,056 |  | 8,242,346 |  | 5,301,054 |  | (42,864) |  | (239,377) |  | 15,057,215 |
Net Income |  |  |  | 351,289 |  |  |  | 351,289 |
Dividends on Common Shares - $0.6375 Per Share |  |  |  | (221,387) |  |  |  | (221,387) |
Dividends on Preferred Stock |  |  |  | (1,880) |  |  |  | (1,880) |
Issuance of Common Shares - $5 par value | 772,867 |  | 3,864 |  | 67,935 |  |  |  |  | 71,799 |
Long-Term Incentive Plan Activity |  |  | 7,407 |  |  |  |  | 7,407 |
Issuance of Treasury Shares | 164,853 |  |  | 10,762 |  |  |  | 3,083 |  | 13,845 |
Capital Stock Expense |  |  | (973) |  |  |  |  | (973) |
Other Comprehensive Income |  |  |  |  | 1,858 |  |  | 1,858 |
Balance as of September 30, 2022 | 347,348,749 |  | $ | 1,799,920 |  | $ | 8,327,477 |  | $ | 5,429,076 |  | $ | (41,006) |  | $ | (236,294) |  | $ | 15,279,173 |

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

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

| For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022
Operating Activities: |  |  |
Net Income | $ | 851,884 |  |  | $ | 1,090,356 |
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: |  |  |
Depreciation | 962,477 |  |  | 885,711 |
Deferred Income Taxes | 78,276 |  |  | 170,752 |
Uncollectible Expense | 40,945 |  |  | 40,753 |
Pension, SERP and PBOP Income, Net | (64,311) |  |  | (120,416) |
Pension Contributions | (5,000) |  |  | (80,000) |
Regulatory Under Recoveries, Net | (4,148) |  |  | (32,193) |
Amortization | (438,460) |  |  | 418,644 |
Cost of Removal Expenditures | (237,368) |  |  | (284,706) |
Customer Credits Distributed in 2022 at CL&P related to PURA Settlement Agreement and Storm Performance Penalty | — |  |  | (72,041) |
Payment in 2022 of Withheld Property Taxes | — |  |  | (78,446) |
Impairment of Offshore Wind Investment | 401,000 |  |  | — |
Other | (114,111) |  |  | (34,702) |
Changes in Current Assets and Liabilities: |  |  |
Receivables and Unbilled Revenues, Net | 6,738 |  |  | (294,383) |
Taxes Receivable/Accrued, Net | 177,618 |  |  | 160,260 |
Accounts Payable | (385,741) |  |  | 11,821 |
Other Current Assets and Liabilities, Net | (100,646) |  |  | (92,506) |
Net Cash Flows Provided by Operating Activities | 1,169,153 |  |  | 1,688,904 |
Investing Activities: |  |  |
Investments in Property, Plant and Equipment | (3,125,617) |  |  | (2,352,743) |
Proceeds from Sales of Marketable Securities | 341,871 |  |  | 340,660 |
Purchases of Marketable Securities | (287,814) |  |  | (313,714) |
Investments in Unconsolidated Affiliates | (887,365) |  |  | (617,588) |
Other Investing Activities | (57) |  |  | 15,245 |
Net Cash Flows Used in Investing Activities | (3,958,982) |  |  | (2,928,140) |
Financing Activities: |  |  |
Issuance of Common Shares, Net of Issuance Costs | — |  |  | 197,108 |
Cash Dividends on Common Shares | (688,878) |  |  | (643,634) |
Cash Dividends on Preferred Stock | (5,639) |  |  | (5,639) |
Increase/(Decrease) in Notes Payable | 87,600 |  |  | (1,103,950) |
Repayment of Rate Reduction Bonds | (43,210) |  |  | (43,210) |
Issuance of Long-Term Debt | 4,340,300 |  |  | 4,045,000 |
Retirement of Long-Term Debt | (1,203,000) |  |  | (775,000) |
Other Financing Activities | (38,189) |  |  | (50,191) |
Net Cash Flows Provided by Financing Activities | 2,448,984 |  |  | 1,620,484 |
Net (Decrease)/Increase in Cash, Cash Equivalents and Restricted Cash | (340,845) |  |  | 381,248 |
Cash, Cash Equivalents and Restricted Cash - Beginning of Period | 521,752 |  |  | 221,008 |
Cash and Restricted Cash - End of Period | $ | 180,907 |  |  | $ | 602,256 |

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

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

(Thousands of Dollars) | As of September 30, 2023 |  | As of December 31, 2022
ASSETS |  |  |
Current Assets: |  |  |
Cash | $ | 9,798 |  |  | $ | 11,312 |
Receivables, Net (net of allowance for uncollectible accounts of $276,337 and $225,320 as of September 30, 2023 and December 31, 2022, respectively) | 629,064 |  |  | 612,052 |
Accounts Receivable from Affiliated Companies | 54,765 |  |  | 46,439 |
Unbilled Revenues | 51,527 |  |  | 59,363 |
Materials, Supplies and REC Inventory | 145,774 |  |  | 88,157 |
Taxes Receivable | 26 |  |  | 65,785 |
Regulatory Assets | 383,672 |  |  | 314,089 |
Prepaid Property Taxes | 79,848 |  |  | 25,281 |
Prepayments and Other Current Assets | 36,216 |  |  | 37,243 |
Total Current Assets | 1,390,690 |  |  | 1,259,721 |
Property, Plant and Equipment, Net | 12,035,967 |  |  | 11,467,024 |
Deferred Debits and Other Assets: |  |  |
Regulatory Assets | 1,598,934 |  |  | 1,593,693 |
Prepaid Pension | 180,485 |  |  | 147,914 |
Other Long-Term Assets | 303,561 |  |  | 290,444 |
Total Deferred Debits and Other Assets | 2,082,980 |  |  | 2,032,051 |
Total Assets | $ | 15,509,637 |  |  | $ | 14,758,796 |
LIABILITIES AND CAPITALIZATION |  |  |
Current Liabilities: |  |  |
Notes Payable to Eversource Parent | $ | 213,400 |  |  | $ | — |
Accounts Payable | 555,676 |  |  | 710,500 |
Accounts Payable to Affiliated Companies | 119,235 |  |  | 136,277 |
Obligations to Third Party Suppliers | 79,211 |  |  | 40,704 |
Regulatory Liabilities | 155,901 |  |  | 336,048 |
Derivative Liabilities | 84,179 |  |  | 81,588 |
Other Current Liabilities | 182,278 |  |  | 123,171 |
Total Current Liabilities | 1,389,880 |  |  | 1,428,288 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated Deferred Income Taxes | 1,778,431 |  |  | 1,640,034 |
Regulatory Liabilities | 1,308,284 |  |  | 1,263,396 |
Derivative Liabilities | 85,322 |  |  | 143,929 |
Other Long-Term Liabilities | 167,651 |  |  | 166,081 |
Total Deferred Credits and Other Liabilities | 3,339,688 |  |  | 3,213,440 |
Long-Term Debt | 4,606,833 |  |  | 4,216,488 |
Preferred Stock Not Subject to Mandatory Redemption | 116,200 |  |  | 116,200 |
Common Stockholder's Equity: |  |  |
Common Stock | 60,352 |  |  | 60,352 |
Capital Surplus, Paid In | 3,384,265 |  |  | 3,260,765 |
Retained Earnings | 2,612,228 |  |  | 2,463,094 |
Accumulated Other Comprehensive Income | 191 |  |  | 169 |
Common Stockholder's Equity | 6,057,036 |  |  | 5,784,380 |
Commitments and Contingencies (Note 9) |  |  |
Total Liabilities and Capitalization | $ | 15,509,637 |  |  | $ | 14,758,796 |

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

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

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022 |  | 2023 |  | 2022
Operating Revenues | $ | 1,190,096 |  |  | $ | 1,369,101 |  |  | $ | 3,563,150 |  |  | $ | 3,690,614 |
Operating Expenses: |  |  |  |  |  |  |
Purchased Power and Transmission | 659,971 |  |  | 641,052 |  |  | 2,136,947 |  |  | 1,585,515 |
Operations and Maintenance | 198,773 |  |  | 189,864 |  |  | 525,655 |  |  | 515,928 |
Depreciation | 95,218 |  |  | 89,468 |  |  | 281,107 |  |  | 264,966 |
Amortization of Regulatory (Liabilities)/Assets, Net | (113,165) |  |  | 105,825 |  |  | (425,402) |  |  | 318,347 |
Energy Efficiency Programs | 39,903 |  |  | 37,934 |  |  | 100,687 |  |  | 103,111 |
Taxes Other Than Income Taxes | 107,037 |  |  | 104,298 |  |  | 303,222 |  |  | 290,449 |
Total Operating Expenses | 987,737 |  |  | 1,168,441 |  |  | 2,922,216 |  |  | 3,078,316 |
Operating Income | 202,359 |  |  | 200,660 |  |  | 640,934 |  |  | 612,298 |
Interest Expense | 52,439 |  |  | 42,391 |  |  | 145,410 |  |  | 125,152 |
Other Income, Net | 18,311 |  |  | 21,927 |  |  | 46,610 |  |  | 61,290 |
Income Before Income Tax Expense | 168,231 |  |  | 180,196 |  |  | 542,134 |  |  | 548,436 |
Income Tax Expense | 48,843 |  |  | 36,909 |  |  | 141,030 |  |  | 126,334 |
Net Income | $ | 119,388 |  |  | $ | 143,287 |  |  | $ | 401,104 |  |  | $ | 422,102 |

The accompanying notes are an integral part of these unaudited condensed financial statements.
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022 |  | 2023 |  | 2022
Net Income | $ | 119,388 |  |  | $ | 143,287 |  |  | $ | 401,104 |  |  | $ | 422,102 |
Other Comprehensive (Loss)/Income, Net of Tax: |  |  |  |  |  |  |
Qualified Cash Flow Hedging Instruments | (7) |  |  | (7) |  |  | (21) |  |  | (20) |
Changes in Unrealized (Losses)/Gains on Marketable Securities | — |  |  | (23) |  |  | 43 |  |  | (68) |
Other Comprehensive (Loss)/Income, Net of Tax | (7) |  |  | (30) |  |  | 22 |  |  | (88) |
Comprehensive Income | $ | 119,381 |  |  | $ | 143,257 |  |  | $ | 401,126 |  |  | $ | 422,014 |

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

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

| For the Nine Months Ended September 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 |
Net Income |  |  |  |  |  |  | 119,388 |  |  |  |  | 119,388 |
Dividends on Preferred Stock |  |  |  |  |  |  | (1,390) |  |  |  |  | (1,390) |
Dividends on Common Stock |  |  |  |  |  |  | (82,600) |  |  |  |  | (82,600) |
Capital Contributions from Eversource Parent |  |  |  |  | 123,500 |  |  |  |  |  |  | 123,500 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (7) |  |  | (7) |
Balance as of September 30, 2023 | 6,035,205 |  |  | $ | 60,352 |  |  | $ | 3,384,265 |  |  | $ | 2,612,228 |  |  | $ | 191 |  |  | $ | 6,057,036 |

| For the Nine Months Ended September 30, 2022
| Common Stock |  | Capital Surplus, Paid In |  | Retained Earnings |  | Accumulated Other Comprehensive Income |  | Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information) | Stock |  | Amount |  |  |  |
Balance as of January 1, 2022 | 6,035,205 |  |  | $ | 60,352 |  |  | $ | 3,010,765 |  |  | $ | 2,228,133 |  |  | $ | 251 |  |  | $ | 5,299,501 |
Net Income |  |  |  |  |  |  | 152,977 |  |  |  |  | 152,977 |
Dividends on Preferred Stock |  |  |  |  |  |  | (1,390) |  |  |  |  | (1,390) |
Dividends on Common Stock |  |  |  |  |  |  | (73,100) |  |  |  |  | (73,100) |
Capital Contributions from Eversource Parent |  |  |  |  | 100,000 |  |  |  |  |  |  | 100,000 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (35) |  |  | (35) |
Balance as of March 31, 2022 | 6,035,205 |  |  | 60,352 |  |  | 3,110,765 |  |  | 2,306,620 |  |  | 216 |  |  | 5,477,953 |
Net Income |  |  |  |  |  |  | 125,838 |  |  |  |  | 125,838 |
Dividends on Preferred Stock |  |  |  |  |  |  | (1,390) |  |  |  |  | (1,390) |
Dividends on Common Stock |  |  |  |  |  |  | (73,100) |  |  |  |  | (73,100) |
Capital Contributions from Eversource Parent |  |  |  |  | 100,000 |  |  |  |  |  |  | 100,000 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (23) |  |  | (23) |
Balance as of June 30, 2022 | 6,035,205 |  |  | 60,352 |  |  | 3,210,765 |  |  | 2,357,968 |  |  | 193 |  |  | 5,629,278 |
Net Income |  |  |  |  |  |  | 143,287 |  |  |  |  | 143,287 |
Dividends on Preferred Stock |  |  |  |  |  |  | (1,390) |  |  |  |  | (1,390) |
Dividends on Common Stock |  |  |  |  |  |  | (73,100) |  |  |  |  | (73,100) |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (30) |  |  | (30) |
Balance as of September 30, 2022 | 6,035,205 |  |  | $ | 60,352 |  |  | $ | 3,210,765 |  |  | $ | 2,426,765 |  |  | $ | 163 |  |  | $ | 5,698,045 |

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

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

| For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022
Operating Activities: |  |  |
Net Income | $ | 401,104 |  |  | $ | 422,102 |
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: |  |  |
Depreciation | 281,107 |  |  | 264,966 |
Deferred Income Taxes | 115,450 |  |  | (18,780) |
Uncollectible Expense | 7,106 |  |  | 10,816 |
Pension, SERP, and PBOP Income, Net | (13,699) |  |  | (21,751) |
Regulatory Over/(Under) Recoveries, Net | 198,519 |  |  | (47,620) |
Customer Credits Distributed in 2022 related to PURA Settlement Agreement and Storm Performance Penalty | — |  |  | (72,041) |
Amortization of Regulatory (Liabilities)/Assets, Net | (425,402) |  |  | 318,347 |
Cost of Removal Expenditures | (56,168) |  |  | (54,145) |
Other | (21,415) |  |  | (19,310) |
Changes in Current Assets and Liabilities: |  |  |
Receivables and Unbilled Revenues, Net | (113,592) |  |  | (271,658) |
Taxes Receivable/Accrued, Net | 107,774 |  |  | 106,737 |
Accounts Payable | (112,946) |  |  | 273 |
Other Current Assets and Liabilities, Net | (47,800) |  |  | (63,682) |
Net Cash Flows Provided by Operating Activities | 320,038 |  |  | 554,254 |
Investing Activities: |  |  |
Investments in Property, Plant and Equipment | (797,282) |  |  | (608,966) |
Other Investing Activities | 173 |  |  | 513 |
Net Cash Flows Used in Investing Activities | (797,109) |  |  | (608,453) |
Financing Activities: |  |  |
Cash Dividends on Common Stock | (247,800) |  |  | (219,300) |
Cash Dividends on Preferred Stock | (4,169) |  |  | (4,169) |
Capital Contributions from Eversource Parent | 123,500 |  |  | 200,000 |
Issuance of Long-Term Debt | 800,000 |  |  | — |
Retirement of Long-Term Debt | (400,000) |  |  | — |
Increase in Notes Payable to Eversource Parent | 213,400 |  |  | 26,000 |
Other Financing Activities | (9,244) |  |  | — |
Net Cash Flows Provided by Financing Activities | 475,687 |  |  | 2,531 |
Net Decrease in Cash and Restricted Cash | (1,384) |  |  | (51,668) |
Cash and Restricted Cash - Beginning of Period | 20,327 |  |  | 74,788 |
Cash and Restricted Cash - End of Period | $ | 18,943 |  |  | $ | 23,120 |

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

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

(Thousands of Dollars) | As of September 30, 2023 |  | As of December 31, 2022
ASSETS |  |  |
Current Assets: |  |  |
Cash | $ | 5,991 |  |  | $ | 738 |
Cash Equivalents | — |  |  | 327,006 |
Receivables, Net (net of allowance for uncollectible accounts of $100,826 and $94,958 as of September 30, 2023 and December 31, 2022, respectively) | 523,997 |  |  | 453,371 |
Accounts Receivable from Affiliated Companies | 48,986 |  |  | 35,196 |
Unbilled Revenues | 46,878 |  |  | 39,680 |
Materials, Supplies and REC Inventory | 140,470 |  |  | 138,352 |
Regulatory Assets | 638,464 |  |  | 492,759 |
Prepayments and Other Current Assets | 73,571 |  |  | 71,276 |
Total Current Assets | 1,478,357 |  |  | 1,558,378 |
Property, Plant and Equipment, Net | 12,409,156 |  |  | 11,626,968 |
Deferred Debits and Other Assets: |  |  |
Regulatory Assets | 1,190,138 |  |  | 1,221,619 |
Prepaid Pension and PBOP | 646,640 |  |  | 576,809 |
Other Long-Term Assets | 119,884 |  |  | 111,846 |
Total Deferred Debits and Other Assets | 1,956,662 |  |  | 1,910,274 |
Total Assets | $ | 15,844,175 |  |  | $ | 15,095,620 |
LIABILITIES AND CAPITALIZATION |  |  |
Current Liabilities: |  |  |
Notes Payable | $ | 209,500 |  |  | $ | — |
Long-Term Debt – Current Portion | 80,000 |  |  | 80,000 |
Accounts Payable | 497,660 |  |  | 559,676 |
Accounts Payable to Affiliated Companies | 113,723 |  |  | 108,907 |
Obligations to Third Party Suppliers | 166,995 |  |  | 142,628 |
Renewable Portfolio Standards Compliance Obligations | 88,938 |  |  | 120,239 |
Regulatory Liabilities | 416,046 |  |  | 373,221 |
Other Current Liabilities | 98,907 |  |  | 83,925 |
Total Current Liabilities | 1,671,769 |  |  | 1,468,596 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated Deferred Income Taxes | 1,812,533 |  |  | 1,700,875 |
Regulatory Liabilities | 1,587,567 |  |  | 1,548,081 |
Other Long-Term Liabilities | 304,228 |  |  | 289,313 |
Total Deferred Credits and Other Liabilities | 3,704,328 |  |  | 3,538,269 |
Long-Term Debt | 4,496,484 |  |  | 4,345,085 |
Preferred Stock Not Subject to Mandatory Redemption | 43,000 |  |  | 43,000 |
Common Stockholder's Equity: |  |  |
Common Stock | — |  |  | — |
Capital Surplus, Paid In | 2,902,542 |  |  | 2,778,942 |
Retained Earnings | 3,025,841 |  |  | 2,921,444 |
Accumulated Other Comprehensive Income | 211 |  |  | 284 |
Common Stockholder's Equity | 5,928,594 |  |  | 5,700,670 |
Commitments and Contingencies (Note 9) |  |  |
Total Liabilities and Capitalization | $ | 15,844,175 |  |  | $ | 15,095,620 |

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

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

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022 |  | 2023 |  | 2022
Operating Revenues | $ | 953,531 |  |  | $ | 1,105,452 |  |  | $ | 2,728,782 |  |  | $ | 2,752,278 |
Operating Expenses: |  |  |  |  |  |  |
Purchased Power and Transmission | 308,999 |  |  | 421,217 |  |  | 936,484 |  |  | 971,754 |
Operations and Maintenance | 174,091 |  |  | 161,770 |  |  | 487,026 |  |  | 475,727 |
Depreciation | 94,103 |  |  | 91,194 |  |  | 277,396 |  |  | 269,928 |
Amortization of Regulatory (Liabilities)/Assets, Net | (6,462) |  |  | 15,940 |  |  | 14,923 |  |  | 65,307 |
Energy Efficiency Programs | 95,351 |  |  | 105,708 |  |  | 252,255 |  |  | 255,230 |
Taxes Other Than Income Taxes | 68,449 |  |  | 65,085 |  |  | 188,191 |  |  | 185,748 |
Total Operating Expenses | 734,531 |  |  | 860,914 |  |  | 2,156,275 |  |  | 2,223,694 |
Operating Income | 219,000 |  |  | 244,538 |  |  | 572,507 |  |  | 528,584 |
Interest Expense | 48,178 |  |  | 41,829 |  |  | 139,804 |  |  | 119,035 |
Other Income, Net | 39,908 |  |  | 37,895 |  |  | 120,690 |  |  | 101,385 |
Income Before Income Tax Expense | 210,730 |  |  | 240,604 |  |  | 553,393 |  |  | 510,934 |
Income Tax Expense | 46,019 |  |  | 52,520 |  |  | 120,126 |  |  | 110,674 |
Net Income | $ | 164,711 |  |  | $ | 188,084 |  |  | $ | 433,267 |  |  | $ | 400,260 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022 |  | 2023 |  | 2022
Net Income | $ | 164,711 |  |  | $ | 188,084 |  |  | $ | 433,267 |  |  | $ | 400,260 |
Other Comprehensive Loss, Net of Tax: |  |  |  |  |  |  |
Changes in Funded Status of SERP Benefit Plan | (35) |  |  | (61) |  |  | (100) |  |  | (132) |
Qualified Cash Flow Hedging Instruments | 5 |  |  | 5 |  |  | 15 |  |  | 15 |
Changes in Unrealized (Losses)/Gains on Marketable Securities | — |  |  | (6) |  |  | 12 |  |  | (19) |
Other Comprehensive Loss, Net of Tax | (30) |  |  | (62) |  |  | (73) |  |  | (136) |
Comprehensive Income | $ | 164,681 |  |  | $ | 188,022 |  |  | $ | 433,194 |  |  | $ | 400,124 |

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

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

| For the Nine Months Ended September 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 |
Net Income |  |  |  |  |  |  | 164,711 |  |  |  |  | 164,711 |
Dividends on Preferred Stock |  |  |  |  |  |  | (490) |  |  |  |  | (490) |
Capital Contributions from Eversource Parent |  |  |  |  | 11,300 |  |  |  |  |  |  | 11,300 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (30) |  |  | (30) |
Balance as of September 30, 2023 | 200 |  |  | $ | — |  |  | $ | 2,902,542 |  |  | $ | 3,025,841 |  |  | $ | 211 |  |  | $ | 5,928,594 |

| For the Nine Months Ended September 30, 2022
| Common Stock |  | Capital Surplus, Paid In |  | Retained Earnings |  | Accumulated Other Comprehensive Income |  | Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information) | Stock |  | Amount |  |  |  |
Balance as of January 1, 2022 | 200 |  |  | $ | — |  |  | $ | 2,253,942 |  |  | $ | 2,718,576 |  |  | $ | 501 |  |  | $ | 4,973,019 |
Net Income |  |  |  |  |  |  | 92,739 |  |  |  |  | 92,739 |
Dividends on Preferred Stock |  |  |  |  |  |  | (490) |  |  |  |  | (490) |
Dividends on Common Stock |  |  |  |  |  |  | (71,900) |  |  |  |  | (71,900) |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (47) |  |  | (47) |
Balance as of March 31, 2022 | 200 |  |  | — |  |  | 2,253,942 |  |  | 2,738,925 |  |  | 454 |  |  | 4,993,321 |
Net Income |  |  |  |  |  |  | 119,437 |  |  |  |  | 119,437 |
Dividends on Preferred Stock |  |  |  |  |  |  | (490) |  |  |  |  | (490) |
Dividends on Common Stock |  |  |  |  |  |  | (71,900) |  |  |  |  | (71,900) |
Capital Contributions from Eversource Parent |  |  |  |  | 50,000 |  |  |  |  |  |  | 50,000 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (27) |  |  | (27) |
Balance as of June 30, 2022 | 200 |  |  | — |  |  | 2,303,942 |  |  | 2,785,972 |  |  | 427 |  |  | 5,090,341 |
Net Income |  |  |  |  |  |  | 188,084 |  |  |  |  | 188,084 |
Dividends on Preferred Stock |  |  |  |  |  |  | (490) |  |  |  |  | (490) |
Dividends on Common Stock |  |  |  |  |  |  | (71,900) |  |  |  |  | (71,900) |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (62) |  |  | (62) |
Balance as of September 30, 2022 | 200 |  |  | $ | — |  |  | $ | 2,303,942 |  |  | $ | 2,901,666 |  |  | $ | 365 |  |  | $ | 5,205,973 |

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

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

| For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022
Operating Activities: |  |  |
Net Income | $ | 433,267 |  |  | $ | 400,260 |
Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: |  |  |
Depreciation | 277,396 |  |  | 269,928 |
Deferred Income Taxes | 72,220 |  |  | 34,025 |
Uncollectible Expense | 12,988 |  |  | 12,159 |
Pension, SERP and PBOP Income, Net | (31,007) |  |  | (41,790) |
Pension Contributions | — |  |  | (15,000) |
Regulatory Under Recoveries, Net | (103,903) |  |  | (36,203) |
Amortization of Regulatory Assets, Net | 14,923 |  |  | 65,307 |
Cost of Removal Expenditures | (49,379) |  |  | (33,467) |
Payment in 2022 of Withheld Property Taxes | — |  |  | (76,084) |
Other | (11,174) |  |  | (8,961) |
Changes in Current Assets and Liabilities: |  |  |
Receivables and Unbilled Revenues, Net | (76,989) |  |  | (67,950) |
Taxes Receivable/Accrued, Net | 61,773 |  |  | 122,467 |
Accounts Payable | (60,363) |  |  | (55,676) |
Other Current Assets and Liabilities, Net | (10,752) |  |  | 65,609 |
Net Cash Flows Provided by Operating Activities | 529,000 |  |  | 634,624 |
Investing Activities: |  |  |
Investments in Property, Plant and Equipment | (1,012,357) |  |  | (691,940) |
Other Investing Activities | 48 |  |  | 143 |
Net Cash Flows Used in Investing Activities | (1,012,309) |  |  | (691,797) |
Financing Activities: |  |  |
Cash Dividends on Common Stock | (327,400) |  |  | (215,700) |
Cash Dividends on Preferred Stock | (1,470) |  |  | (1,470) |
Issuance of Long-Term Debt | 150,000 |  |  | 850,000 |
Capital Contributions from Eversource Parent | 123,600 |  |  | 50,000 |
Increase in Notes Payable to Eversource Parent | — |  |  | 2,800 |
Increase/(Decrease) in Notes Payable | 209,500 |  |  | (162,500) |
Other Financing Activities | (1,368) |  |  | (13,191) |
Net Cash Flows Provided by Financing Activities | 152,862 |  |  | 509,939 |
Net (Decrease)/Increase in Cash, Cash Equivalents and Restricted Cash | (330,447) |  |  | 452,766 |
Cash, Cash Equivalents and Restricted Cash - Beginning of Period | 345,293 |  |  | 18,179 |
Cash and Restricted Cash - End of Period | $ | 14,846 |  |  | $ | 470,945 |

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 BALANCE SHEETS
(Unaudited)

(Thousands of Dollars) | As of September 30, 2023 |  | As of December 31, 2022
ASSETS |  |  |
Current Assets: |  |  |
Cash | $ | 33,943 |  |  | $ | 136 |
Receivables, Net (net of allowance for uncollectible accounts of $12,408 and $29,236 as of September 30, 2023 and December 31, 2022, respectively) | 159,704 |  |  | 173,337 |
Accounts Receivable from Affiliated Companies | 17,139 |  |  | 8,193 |
Unbilled Revenues | 44,540 |  |  | 72,713 |
Taxes Receivable | 24,280 |  |  | 27,978 |
Materials, Supplies and REC Inventory | 59,555 |  |  | 34,521 |
Regulatory Assets | 177,120 |  |  | 102,240 |
Special Deposits | 18,185 |  |  | 33,140 |
Prepayments and Other Current Assets | 2,900 |  |  | 13,297 |
Total Current Assets | 537,366 |  |  | 465,555 |
Property, Plant and Equipment, Net | 4,433,033 |  |  | 4,060,224 |
Deferred Debits and Other Assets: |  |  |
Regulatory Assets | 739,372 |  |  | 593,974 |
Prepaid Pension | 83,111 |  |  | 66,384 |
Other Long-Term Assets | 11,997 |  |  | 16,517 |
Total Deferred Debits and Other Assets | 834,480 |  |  | 676,875 |
Total Assets | $ | 5,804,879 |  |  | $ | 5,202,654 |
LIABILITIES AND CAPITALIZATION |  |  |
Current Liabilities: |  |  |
Notes Payable to Eversource Parent | $ | 100 |  |  | $ | 173,300 |
Long-Term Debt – Current Portion | 325,000 |  |  | 29,668 |
Rate Reduction Bonds – Current Portion | 43,210 |  |  | 43,210 |
Accounts Payable | 193,802 |  |  | 291,556 |
Accounts Payable to Affiliated Companies | 35,920 |  |  | 36,231 |
Regulatory Liabilities | 114,561 |  |  | 161,963 |
Other Current Liabilities | 83,046 |  |  | 59,616 |
Total Current Liabilities | 795,639 |  |  | 795,544 |
Deferred Credits and Other Liabilities: |  |  |
Accumulated Deferred Income Taxes | 668,174 |  |  | 562,802 |
Regulatory Liabilities | 391,013 |  |  | 391,628 |
Other Long-Term Liabilities | 40,931 |  |  | 37,087 |
Total Deferred Credits and Other Liabilities | 1,100,118 |  |  | 991,517 |
Long-Term Debt | 1,431,584 |  |  | 1,134,914 |
Rate Reduction Bonds | 367,282 |  |  | 410,492 |
Common Stockholder's Equity: |  |  |
Common Stock | — |  |  | — |
Capital Surplus, Paid In | 1,498,134 |  |  | 1,298,134 |
Retained Earnings | 612,122 |  |  | 572,126 |
Accumulated Other Comprehensive Loss | — |  |  | (73) |
Common Stockholder's Equity | 2,110,256 |  |  | 1,870,187 |
Commitments and Contingencies (Note 9) |  |  |
Total Liabilities and Capitalization | $ | 5,804,879 |  |  | $ | 5,202,654 |

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 INCOME
(Unaudited)

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022 |  | 2023 |  | 2022
Operating Revenues | $ | 353,074 |  |  | $ | 430,642 |  |  | $ | 1,123,300 |  |  | $ | 1,077,124 |
Operating Expenses: |  |  |  |  |  |  |
Purchased Power and Transmission | 128,040 |  |  | 215,360 |  |  | 499,553 |  |  | 452,007 |
Operations and Maintenance | 85,230 |  |  | 67,811 |  |  | 217,529 |  |  | 194,114 |
Depreciation | 35,517 |  |  | 32,187 |  |  | 104,307 |  |  | 94,997 |
Amortization of Regulatory (Liabilities)/Assets, Net | (9,963) |  |  | 7,398 |  |  | (35,234) |  |  | 43,449 |
Energy Efficiency Programs | 11,097 |  |  | 11,142 |  |  | 30,473 |  |  | 28,678 |
Taxes Other Than Income Taxes | 25,748 |  |  | 25,331 |  |  | 73,384 |  |  | 73,377 |
Total Operating Expenses | 275,669 |  |  | 359,229 |  |  | 890,012 |  |  | 886,622 |
Operating Income | 77,405 |  |  | 71,413 |  |  | 233,288 |  |  | 190,502 |
Interest Expense | 19,252 |  |  | 15,030 |  |  | 55,901 |  |  | 43,432 |
Other Income, Net | 7,180 |  |  | 8,073 |  |  | 19,199 |  |  | 23,365 |
Income Before Income Tax Expense | 65,333 |  |  | 64,456 |  |  | 196,586 |  |  | 170,435 |
Income Tax Expense | 13,995 |  |  | 13,009 |  |  | 44,590 |  |  | 36,364 |
Net Income | $ | 51,338 |  |  | $ | 51,447 |  |  | $ | 151,996 |  |  | $ | 134,071 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022 |  | 2023 |  | 2022
Net Income | $ | 51,338 |  |  | $ | 51,447 |  |  | $ | 151,996 |  |  | $ | 134,071 |
Other Comprehensive (Loss)/Income, Net of Tax: |  |  |  |  |  |  |
Changes in Unrealized (Losses)/Gains on Marketable Securities | — |  |  | (39) |  |  | 73 |  |  | (117) |
Other Comprehensive (Loss)/Income, Net of Tax | — |  |  | (39) |  |  | 73 |  |  | (117) |
Comprehensive Income | $ | 51,338 |  |  | $ | 51,408 |  |  | $ | 152,069 |  |  | $ | 133,954 |

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 COMMON STOCKHOLDER'S EQUITY
(Unaudited)

| For the Nine Months Ended September 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 |
Net Income |  |  |  |  |  |  | 51,338 |  |  |  |  | 51,338 |
Dividends on Common Stock |  |  |  |  |  |  | (56,000) |  |  |  |  | (56,000) |
Capital Contributions from Eversource Parent |  |  |  |  | 100,000 |  |  |  |  |  |  | 100,000 |
Balance as of September 30, 2023 | 301 |  |  | $ | — |  |  | $ | 1,498,134 |  |  | $ | 612,122 |  |  | $ | — |  |  | $ | 2,110,256 |

| For the Nine Months Ended September 30, 2022
| Common Stock |  | Capital Surplus, Paid In |  | Retained Earnings |  | Accumulated Other Comprehensive Income/(Loss) |  | Total Common Stockholder's Equity
(Thousands of Dollars, Except Stock Information) | Stock |  | Amount |  |  |  |
Balance as of January 1, 2022 | 301 |  |  | $ | — |  |  | $ | 1,088,134 |  |  | $ | 504,556 |  |  | $ | 23 |  |  | $ | 1,592,713 |
Net Income |  |  |  |  |  |  | 45,586 |  |  |  |  | 45,586 |
Dividends on Common Stock |  |  |  |  |  |  | (26,000) |  |  |  |  | (26,000) |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (48) |  |  | (48) |
Balance as of March 31, 2022 | 301 |  |  | — |  |  | 1,088,134 |  |  | 524,142 |  |  | (25) |  |  | 1,612,251 |
Net Income |  |  |  |  |  |  | 37,038 |  |  |  |  | 37,038 |
Dividends on Common Stock |  |  |  |  |  |  | (26,000) |  |  |  |  | (26,000) |
Capital Contributions from Eversource Parent |  |  |  |  | 180,000 |  |  |  |  |  |  | 180,000 |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (30) |  |  | (30) |
Balance as of June 30, 2022 | 301 |  |  | — |  |  | 1,268,134 |  |  | 535,180 |  |  | (55) |  |  | 1,803,259 |
Net Income |  |  |  |  |  |  | 51,447 |  |  |  |  | 51,447 |
Dividends on Common Stock |  |  |  |  |  |  | (26,000) |  |  |  |  | (26,000) |
Other Comprehensive Loss |  |  |  |  |  |  |  |  | (39) |  |  | (39) |
Balance as of September 30, 2022 | 301 |  |  | $ | — |  |  | $ | 1,268,134 |  |  | $ | 560,627 |  |  | $ | (94) |  |  | $ | 1,828,667 |

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

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

| For the Nine Months Ended September 30,
(Thousands of Dollars) | 2023 |  | 2022
Operating Activities: |  |  |
Net Income | $ | 151,996 |  |  | $ | 134,071 |
Adjustments to Reconcile Net Income to Net Cash Flows (Used In)/Provided by Operating Activities: |  |  |
Depreciation | 104,307 |  |  | 94,997 |
Deferred Income Taxes | 96,711 |  |  | (12,212) |
Uncollectible Expense | 1,534 |  |  | 8,060 |
Pension, SERP and PBOP Income, Net | (7,841) |  |  | (12,269) |
Regulatory (Under)/Over Recoveries, Net | (251,048) |  |  | 63,423 |
Amortization of Regulatory (Liabilities)/Assets, Net | (35,234) |  |  | 43,449 |
Cost of Removal Expenditures | (29,448) |  |  | (25,682) |
Other | 11,479 |  |  | 10,317 |
Changes in Current Assets and Liabilities: |  |  |
Receivables and Unbilled Revenues, Net | 4,011 |  |  | (66,751) |
Taxes Receivable/Accrued, Net | 27,797 |  |  | 20,986 |
Accounts Payable | (70,102) |  |  | (3,969) |
Other Current Assets and Liabilities, Net | (17,092) |  |  | (7,681) |
Net Cash Flows (Used In)/Provided by Operating Activities | (12,930) |  |  | 246,739 |
Investing Activities: |  |  |
Investments in Property, Plant and Equipment | (431,937) |  |  | (346,318) |
Other Investing Activities | 296 |  |  | 879 |
Net Cash Flows Used in Investing Activities | (431,641) |  |  | (345,439) |
Financing Activities: |  |  |
Cash Dividends on Common Stock | (112,000) |  |  | (78,000) |
Capital Contributions from Eversource Parent | 200,000 |  |  | 180,000 |
Issuance of Long-Term Debt | 600,000 |  |  | — |
Repayment of Rate Reduction Bonds | (43,210) |  |  | (43,210) |
(Decrease)/Increase in Notes Payable to Eversource Parent | (173,200) |  |  | 29,100 |
Other Financing Activities | (8,524) |  |  | (70) |
Net Cash Flows Provided by Financing Activities | 463,066 |  |  | 87,820 |
Net Increase/(Decrease) in Cash and Restricted Cash | 18,495 |  |  | (10,880) |
Cash and Restricted Cash - Beginning of Period | 36,812 |  |  | 35,126 |
Cash and Restricted Cash - End of Period | $ | 55,307 |  |  | $ | 24,246 |

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.
17

EVERSOURCE ENERGY AND SUBSIDIARIES
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
COMBINED NOTES TO CONDENSED FINANCIAL STATEMENTS (Unaudited)
Refer to the Glossary of Terms included in this combined Quarterly Report on Form 10-Q for abbreviations and acronyms used throughout the combined notes to the unaudited condensed financial statements.
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
A. Basis of Presentation
Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business. Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), Yankee Gas, NSTAR Gas and EGMA (natural gas utilities), and Aquarion (water utilities). Eversource provides energy delivery and/or water service to approximately 4.4 million electric, natural gas and water customers through twelve regulated utilities in Connecticut, Massachusetts and New Hampshire.
The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH include the accounts of each of their respective subsidiaries. Intercompany transactions have been eliminated in consolidation. The accompanying unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P are herein collectively referred to as the "financial statements."
The combined notes to the financial statements have been prepared pursuant to the rules and regulations of the SEC. Certain information and footnote disclosures included in annual financial statements prepared in accordance with GAAP have been omitted pursuant to such rules and regulations. The accompanying financial statements should be read in conjunction with the Combined Notes to Financial Statements included in Item 8, "Financial Statements and Supplementary Data," of the Eversource 2022 Form 10-K, which was filed with the SEC on February 15, 2023. The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
The financial statements contain, in the opinion of management, all adjustments (including normal, recurring adjustments) necessary to present fairly Eversource's, CL&P's, NSTAR Electric's and PSNH's financial position as of September 30, 2023 and December 31, 2022, and the results of operations, comprehensive income and common shareholders' equity for the three and nine months ended September 30, 2023 and 2022, and the cash flows for the nine months ended September 30, 2023 and 2022. The results of operations and comprehensive income for the three and nine months ended September 30, 2023 and 2022 and the cash flows for the nine months ended September 30, 2023 and 2022 are not necessarily indicative of the results expected for a full year.
CYAPC and YAEC are inactive regional nuclear power companies engaged in the long-term storage of their spent nuclear fuel. Eversource consolidates the operations of CYAPC and YAEC because CL&P's, NSTAR Electric's and PSNH's combined ownership and voting interests in each of these entities is greater than 50 percent. Intercompany transactions between CL&P, NSTAR Electric, PSNH and the CYAPC and YAEC companies have been eliminated in consolidation of the Eversource financial statements.
Eversource holds several equity ownership interests that are not consolidated and are accounted for under the equity method.
Eversource's utility subsidiaries' electric, natural gas and water distribution and transmission businesses are subject to rate-regulation that is based on cost recovery and meets the criteria for application of accounting guidance for entities with rate-regulated operations, which considers the effect of regulation on the differences in the timing of the recognition of certain revenues and expenses from those of other businesses and industries. See Note 2, "Regulatory Accounting," for further information.
Certain reclassifications of prior period data were made in the accompanying financial statements to conform to the current period presentation.
B. Allowance for Uncollectible Accounts
Receivables, Net on the balance sheets primarily includes trade receivables from retail customers and customers related to wholesale transmission contracts, wholesale market sales, sales of RECs, and property rentals. Receivables, Net also includes customer receivables for the purchase of electricity from a competitive third party supplier, the current portion of customer energy efficiency loans, property damage receivables and other miscellaneous receivables. There is no material concentration of receivables.
Receivables are recorded at amortized cost, net of a credit loss provision (or allowance for uncollectible accounts). The current expected credit loss (CECL) model is applied to receivables for purposes of calculating the allowance for uncollectible accounts. This model is based on expected losses and results in the recognition of estimated expected credit losses, including uncollectible amounts for both billed and unbilled revenues, over the life of the receivable at the time a receivable is recorded.
18

The allowance for uncollectible accounts is determined based upon a variety of judgments and factors, including an aging-based quantitative assessment that applies an estimated uncollectible percentage to each receivable aging category. Factors in determining credit loss include historical collection, write-off experience, analysis of delinquency statistics, and management's assessment of collectability from customers, including current economic conditions, customer payment trends, the impact on customer bills because of energy usage trends and changes in rates, flexible payment plans and financial hardship arrearage management programs being offered to customers, reasonable forecasts, and expectations of future collectability and collection efforts. Management continuously assesses the collectability of receivables and adjusts estimates based on actual experience and future expectations based on economic conditions, collection efforts and other factors. Management also monitors the aging analysis of receivables to determine if there are changes in the collections of accounts receivable. Receivable balances are written off against the allowance for uncollectible accounts when the customer accounts are no longer in service and these balances are deemed to be uncollectible. Management concluded that the reserve balance as of September 30, 2023 adequately reflected the collection risk and net realizable value for its receivables.
As of both September 30, 2023 and December 31, 2022, the total amount incurred as a result of COVID-19 included in the allowance for uncollectible accounts was $50.9 million at Eversource, $16.0 million at CL&P, and $4.1 million at NSTAR Electric. At our Connecticut and Massachusetts utilities, the COVID-19 related uncollectible amounts were deferred either as incremental regulatory costs or deferred through existing regulatory tracking mechanisms that recover uncollectible energy supply costs, as management believes it is probable that these costs will ultimately be recovered from customers in future rates. No COVID-19 related uncollectible amounts were deferred at PSNH as a result of a July 2021 NHPUC order. Based on the status of our COVID-19 regulatory dockets, policies and practices in the jurisdictions in which we operate, we believe the state regulatory commissions in Connecticut and Massachusetts will allow us to recover our incremental uncollectible customer receivable costs associated with COVID-19.
The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively. The DPU allows NSTAR Electric, NSTAR Gas and EGMA to recover in rates amounts associated with certain uncollectible hardship accounts receivable. These uncollectible hardship customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets. Hardship customers are protected from shut-off in certain circumstances, and historical collection experience has reflected a higher default risk as compared to the rest of the receivable population. Management uses a higher credit risk profile for this pool of trade receivables as compared to non-hardship receivables. The allowance for uncollectible hardship accounts is included in the total uncollectible allowance balance.
The total allowance for uncollectible accounts is included in Receivables, Net on the balance sheets. The activity in the allowance for uncollectible accounts by portfolio segment as of September 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 (2)
Three Months Ended 2023 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Beginning Balance | $ | 338.2 |  |  | $ | 194.2 |  |  | $ | 532.4 |  |  | $ | 226.5 |  |  | $ | 36.3 |  |  | $ | 262.8 |  |  | $ | 45.6 |  |  | $ | 52.2 |  |  | $ | 97.8 |  |  | $ | 12.7 |
Uncollectible Expense | — |  |  | 16.8 |  |  | 16.8 |  |  | — |  |  | 2.4 |  |  | 2.4 |  |  | — |  |  | 5.2 |  |  | 5.2 |  |  | 2.0 |
Uncollectible Costs Deferred (1) | 33.9 |  |  | 14.0 |  |  | 47.9 |  |  | 29.4 |  |  | 3.1 |  |  | 32.5 |  |  | 3.4 |  |  | 4.5 |  |  | 7.9 |  |  | 1.1 |
Write-Offs | (17.5) |  |  | (40.4) |  |  | (57.9) |  |  | (14.9) |  |  | (7.6) |  |  | (22.5) |  |  | 0.1 |  |  | (11.5) |  |  | (11.4) |  |  | (3.6) |
Recoveries Collected | 0.2 |  |  | 3.3 |  |  | 3.5 |  |  | 0.2 |  |  | 0.9 |  |  | 1.1 |  |  | — |  |  | 1.3 |  |  | 1.3 |  |  | 0.2 |
Ending Balance | $ | 354.8 |  |  | $ | 187.9 |  |  | $ | 542.7 |  |  | $ | 241.2 |  |  | $ | 35.1 |  |  | $ | 276.3 |  |  | $ | 49.1 |  |  | $ | 51.7 |  |  | $ | 100.8 |  |  | $ | 12.4 |
Nine 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 | — |  |  | 40.9 |  |  | 40.9 |  |  | — |  |  | 7.1 |  |  | 7.1 |  |  | — |  |  | 13.0 |  |  | 13.0 |  |  | 1.5 |
Uncollectible Costs Deferred (1) | 104.7 |  |  | 22.8 |  |  | 127.5 |  |  | 80.3 |  |  | 9.3 |  |  | 89.6 |  |  | 5.8 |  |  | 13.8 |  |  | 19.6 |  |  | (11.1) |
Write-Offs | (35.3) |  |  | (88.5) |  |  | (123.8) |  |  | (29.0) |  |  | (21.3) |  |  | (50.3) |  |  | (0.4) |  |  | (30.4) |  |  | (30.8) |  |  | (7.8) |
Recoveries Collected | 1.0 |  |  | 10.8 |  |  | 11.8 |  |  | 1.0 |  |  | 3.6 |  |  | 4.6 |  |  | — |  |  | 4.0 |  |  | 4.0 |  |  | 0.6 |
Ending Balance | $ | 354.8 |  |  | $ | 187.9 |  |  | $ | 542.7 |  |  | $ | 241.2 |  |  | $ | 35.1 |  |  | $ | 276.3 |  |  | $ | 49.1 |  |  | $ | 51.7 |  |  | $ | 100.8 |  |  | $ | 12.4 |

19

| 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 2022 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Beginning Balance | $ | 242.7 |  |  | $ | 215.1 |  |  | $ | 457.8 |  |  | $ | 152.1 |  |  | $ | 40.6 |  |  | $ | 192.7 |  |  | $ | 45.0 |  |  | $ | 55.5 |  |  | $ | 100.5 |  |  | $ | 27.3 |
Uncollectible Expense | — |  |  | 10.7 |  |  | 10.7 |  |  | — |  |  | 4.1 |  |  | 4.1 |  |  | — |  |  | 3.5 |  |  | 3.5 |  |  | 3.5 |
Uncollectible Costs Deferred (1) | 15.6 |  |  | 9.4 |  |  | 25.0 |  |  | 11.3 |  |  | 2.0 |  |  | 13.3 |  |  | 2.8 |  |  | 4.0 |  |  | 6.8 |  |  | 0.1 |
Write-Offs | (6.5) |  |  | (33.2) |  |  | (39.7) |  |  | (5.0) |  |  | (7.7) |  |  | (12.7) |  |  | (0.3) |  |  | (12.3) |  |  | (12.6) |  |  | (2.3) |
Recoveries Collected | 0.3 |  |  | 3.5 |  |  | 3.8 |  |  | 0.2 |  |  | 1.0 |  |  | 1.2 |  |  | — |  |  | 1.3 |  |  | 1.3 |  |  | 0.2 |
Ending Balance | $ | 252.1 |  |  | $ | 205.5 |  |  | $ | 457.6 |  |  | $ | 158.6 |  |  | $ | 40.0 |  |  | $ | 198.6 |  |  | $ | 47.5 |  |  | $ | 52.0 |  |  | $ | 99.5 |  |  | $ | 28.8 |
Nine Months Ended 2022 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Beginning Balance | $ | 226.1 |  |  | $ | 191.3 |  |  | $ | 417.4 |  |  | $ | 144.6 |  |  | $ | 36.7 |  |  | $ | 181.3 |  |  | $ | 43.3 |  |  | $ | 53.7 |  |  | $ | 97.0 |  |  | $ | 24.3 |
Uncollectible Expense | — |  |  | 40.8 |  |  | 40.8 |  |  | — |  |  | 10.8 |  |  | 10.8 |  |  | — |  |  | 12.2 |  |  | 12.2 |  |  | 8.1 |
Uncollectible Costs Deferred (1) | 38.0 |  |  | 36.7 |  |  | 74.7 |  |  | 22.3 |  |  | 2.0 |  |  | 24.3 |  |  | 4.9 |  |  | 11.8 |  |  | 16.7 |  |  | 1.2 |
Write-Offs | (13.5) |  |  | (76.3) |  |  | (89.8) |  |  | (9.4) |  |  | (14.4) |  |  | (23.8) |  |  | (0.7) |  |  | (30.6) |  |  | (31.3) |  |  | (5.4) |
Recoveries Collected | 1.5 |  |  | 13.0 |  |  | 14.5 |  |  | 1.1 |  |  | 4.9 |  |  | 6.0 |  |  | — |  |  | 4.9 |  |  | 4.9 |  |  | 0.6 |
Ending Balance | $ | 252.1 |  |  | $ | 205.5 |  |  | $ | 457.6 |  |  | $ | 158.6 |  |  | $ | 40.0 |  |  | $ | 198.6 |  |  | $ | 47.5 |  |  | $ | 52.0 |  |  | $ | 99.5 |  |  | $ | 28.8 |

(1) These expected credit losses are deferred as regulatory costs on the balance sheets, as these amounts are ultimately recovered in rates. Amounts include uncollectible costs for hardship accounts and other customer receivables, including uncollectible amounts related to uncollectible energy supply costs and COVID-19. The increase in the allowance for uncollectible hardship accounts in 2023 at Eversource and CL&P primarily relates to increased customer enrollment in disconnection prevention programs in Connecticut.
(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 1E, “Summary of Significant Accounting Policies - Investments in Unconsolidated Affiliates,” Note 4, "Derivative Instruments," Note 5, "Marketable Securities," and Note 10, "Fair Value of Financial Instruments," to the financial statements.
20

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

| For the Three Months Ended
| September 30, 2023 |  | September 30, 2022
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Pension, SERP and PBOP Non-Service Income Components, Net of Deferred Portion | $ | 28.5 |  |  | $ | 7.0 |  |  | $ | 12.9 |  |  | $ | 3.7 |  |  | $ | 55.3 |  |  | $ | 16.2 |  |  | $ | 21.6 |  |  | $ | 6.8 |
AFUDC Equity | 21.0 |  |  | 5.2 |  |  | 12.5 |  |  | 1.6 |  |  | 12.6 |  |  | 3.7 |  |  | 6.5 |  |  | 0.7 |
Equity in Earnings of Unconsolidated Affiliates | 2.7 |  |  | — |  |  | 0.1 |  |  | — |  |  | 3.8 |  |  | — |  |  | 0.1 |  |  | — |
Investment Income | 2.7 |  |  | 1.5 |  |  | 0.7 |  |  | 0.4 |  |  | 1.3 |  |  | 0.2 |  |  | 0.4 |  |  | 0.2 |
Interest Income | 24.1 |  |  | 4.6 |  |  | 13.6 |  |  | 1.5 |  |  | 14.1 |  |  | 1.8 |  |  | 9.2 |  |  | 0.4 |
Other | 0.1 |  |  | — |  |  | 0.1 |  |  | — |  |  | 2.7 |  |  | — |  |  | 0.1 |  |  | — |
Total Other Income, Net | $ | 79.1 |  |  | $ | 18.3 |  |  | $ | 39.9 |  |  | $ | 7.2 |  |  | $ | 89.8 |  |  | $ | 21.9 |  |  | $ | 37.9 |  |  | $ | 8.1 |
| For the Nine Months Ended
| September 30, 2023 |  | September 30, 2022
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Pension, SERP and PBOP Non-Service Income Components, Net of Deferred Portion | $ | 96.6 |  |  | $ | 24.9 |  |  | $ | 41.7 |  |  | $ | 11.8 |  |  | $ | 164.5 |  |  | $ | 48.3 |  |  | $ | 64.0 |  |  | $ | 20.1 |
AFUDC Equity | 55.5 |  |  | 13.9 |  |  | 34.0 |  |  | 3.4 |  |  | 33.7 |  |  | 9.3 |  |  | 17.5 |  |  | 1.7 |
Equity in Earnings of Unconsolidated Affiliates (1) | 11.5 |  |  | — |  |  | 0.3 |  |  | — |  |  | 20.8 |  |  | — |  |  | 0.2 |  |  | — |
Investment (Loss)/Income | (0.4) |  |  | (0.2) |  |  | 0.5 |  |  | — |  |  | 2.4 |  |  | (0.9) |  |  | 0.6 |  |  | 0.5 |
Interest Income | 68.6 |  |  | 8.0 |  |  | 44.0 |  |  | 3.6 |  |  | 30.3 |  |  | 4.6 |  |  | 18.8 |  |  | 1.1 |
Other (1) | 31.2 |  |  | — |  |  | 0.2 |  |  | 0.4 |  |  | 3.6 |  |  | — |  |  | 0.3 |  |  | — |
Total Other Income, Net | $ | 263.0 |  |  | $ | 46.6 |  |  | $ | 120.7 |  |  | $ | 19.2 |  |  | $ | 255.3 |  |  | $ | 61.3 |  |  | $ | 101.4 |  |  | $ | 23.4 |

(1) 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 2023 within Other in the table above. See Note 1E, "Summary of Significant Accounting Policies - Investments in Unconsolidated Affiliates," for further information. For the nine months ended September 30, 2022, pre-tax income of $12.2 million associated with this investment was included in Equity in Earnings of Unconsolidated Affiliates within Other Income, Net in the table above.
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 September 30, 2023 |  | As of December 31, 2022
Offshore Wind Business | 50 | % |  | $ | 2,578.6 |  |  | $ | 1,947.1 |
Natural Gas Pipeline - Algonquin Gas Transmission, LLC | 15 | % |  | 116.8 |  |  | 118.8 |
Renewable Energy Investment Fund | 90 | % |  | — |  |  | 84.1 |
Other | various |  | 28.5 |  |  | 26.1 |
Total Investments in Unconsolidated Affiliates |  |  | $ | 2,723.9 |  |  | $ | 2,176.1 |

Equity method investments are assessed for impairment when conditions exist that indicate that the fair value of the investment is less than book value. Eversource continually monitors and evaluates its equity method investments to determine if there are indicators of an other-than-temporary impairment. 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. 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.
Offshore Wind Business: Eversource’s offshore wind business includes 50 percent ownership interests in North East Offshore and South Fork Class B Member, LLC, which collectively hold PPAs for the Revolution Wind and South Fork Wind projects and an Offshore Wind Renewable Energy Certificate (OREC) contract for the Sunrise Wind project. Eversource’s offshore wind business also includes a tax equity investment in South Fork Wind through a 100 percent ownership in South Fork Wind Holdings, LLC Class A shares. The offshore wind projects are being developed and constructed through joint and equal partnerships with Ørsted.
On May 25, 2023, Eversource announced that it had completed the strategic review of its offshore wind investment portfolio and determined that it would continue to pursue the sale of its offshore wind investment. The sale process of Eversource’s existing 50 percent interest in its three jointly-owned, contracted offshore wind projects continues to progress, and Eversource anticipates an announcement in the near term.
21

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. Eversource and Ørsted had entered into the purchase and sale agreement of this uncommitted lease area on May 25, 2023.
In September of 2023, Eversource and Ørsted executed a Tax Equity Capital Contribution Agreement for South Fork Wind and funded this tax equity investment. Eversource made a contribution of $528 million using the proceeds from the lease area sale to provide tax equity for South Fork Wind through this new tax equity member interest. In exchange for its investment, Eversource expects to receive investment tax credits as turbines are placed in service for South Fork Wind. These credits will be utilized to reduce Eversource’s federal tax liability, including refunds expected over the next twelve to eighteen months. South Fork Wind is expected to be fully in-service in early 2024.
In the second quarter of 2023, in connection with the conclusion of the strategic review, Eversource evaluated its aggregate investment in the projects, uncommitted lease area, and other related capitalized costs and determined that the carrying value of the equity method offshore wind investment exceeded the fair value of the investment and that the decline was other-than-temporary. The estimate of fair value was based on future cash flows arising from the expected sale price of Eversource’s 50 percent interest in the three contracted projects based on the most recent bid value, the sale price of the uncommitted lease area included in the purchase and sale agreement, expected investment tax credits and potential investment tax credit adder amounts, and the value of the tax equity ownership interest. As a result, Eversource recognized a pre-tax other-than-temporary impairment charge of $401.0 million ($331.0 million after-tax, which includes the impact of a $40 million valuation allowance for federal and state capital loss carryforwards) in the second quarter of 2023.
The impairment evaluation involved judgments in developing the estimate and timing of future cash flows arising from the anticipated sale transactions, including future project spending amounts that could reduce the ultimate sales value, expected ability to qualify the Revolution Wind and Sunrise Wind projects for investment tax credit adders, the expectation of improved Sunrise Wind OREC contract value, and the selection of the discount rate used to determine fair value, all of which are Level 3 fair value measurements. The assumptions used in the discounted cash flow analysis are subject to inherent uncertainties and subjectivity. The use of different assumptions, estimates, or judgments with respect to the estimation of future cash flows could materially increase the impairment charge. The impairment evaluation was based on best information available at the impairment assessment date. Management evaluated its investment as of September 30, 2023 and concluded that, considering all facts and circumstances as of that date, there were no impairment triggering events in the third quarter of 2023. Accordingly, no additional impairment charge was applicable.
The impairment valuation model includes a key judgment of future cash flows from the sale of the Sunrise Wind project of up to $450 million, which was based on the expectation of a successful repricing of the Sunrise Wind OREC contract. In June 2023, Sunrise Wind had filed a petition with the New York State Public Service Commission for an order authorizing NYSERDA to amend the Sunrise Wind OREC contract to incorporate interconnection costs and to provide for inflation adjustments. This value for Sunrise Wind was assessed through September 30, 2023, assuming that the contract repricing would be successful given NYSERDA’s public support for pricing adjustments. On October 12, 2023, the New York State Public Service Commission denied this petition. New York is in the process of establishing an expedited offshore wind renewable energy solicitation, with NYSERDA issuing a request for information to potential bidders on October 26, 2023. Eversource and Ørsted are evaluating the next steps in this re-bidding process. Given the unfavorable development on the OREC pricing denial in the fourth quarter of 2023, Eversource will evaluate the project’s next steps and probability of success in the New York re-bidding process. It is possible that adverse developments could impact the fair value of Sunrise Wind and could result in a significant impairment in a future period.
Another key assumption in the impairment model of our offshore wind investment was investment tax credit (“ITC”) adders that were included in the Inflation Reduction Act. An ITC adder is an additional 10 percent of credit value for ITC eligible costs and include two distinct qualifications related to either using domestic sourced materials (domestic content) or construction of an onshore substation in a designated community (energy communities). Similar to the base ITC of 30 percent of the eligible costs, any ITC adders generated would be used to reduce Eversource’s current federal tax liability and could be used to receive tax refunds from prior years as well. Management estimated in the second quarter of 2023 that it would be able to realize a 10 percent ITC adder for both the Sunrise Wind and Revolution Wind projects, which is a total expected value of approximately $400 million. There is uncertainty at this time as to whether or not those ITC adders can be achieved, and management continues to evaluate the project’s qualifications and to monitor guidance issued by the United States Treasury Department. A change in the expected value or qualification of ITC adders could result in a significant impairment in a future period.
The three contracted offshore wind projects also are facing construction and scheduling related pressures, which may cause additional required capital contributions from Eversource that are not factored into the expected sales price. It is possible that these future spending amounts could result in a significant impairment charge in a future period.
Management will continue to monitor and evaluate all facts and circumstances in the offshore wind sales process and the impact on its investment balance. The fair value of the investment will be updated based on changes in critical assumptions, the final sales price, and final sales terms. It is possible that there will be changes in our expectations of the timing of the sale of our three projects. Adverse changes in facts and circumstances of estimates and timing of future cash flows and the factors described above could result in the recognition of additional, significant impairment charges and could be material to the financial statements.
The impairment charge was a non-cash charge and did not impact Eversource’s cash position. Eversource will continue to make future cash expenditures for required cash contributions to its offshore wind investment up to the time of the sale of the offshore wind projects. Proceeds from the transaction will be used to pay off parent company debt. Eversource’s expected sale of its offshore wind investment does not impact the presentation of the September 30, 2023 financial statements.
22

Proceeds received from the sale of the uncommitted lease area and the contribution for the tax equity investment in South Fork Wind, along with continued capital contributions in the offshore wind investment, are included in Investments in Unconsolidated Affiliates within investing activities on the statement of cash flows for the nine months ended September 30, 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 totaled $147.0 million and are included in Investments in Unconsolidated Affiliates within investing activities on the statement of cash flows. 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 Nine Months Ended
(Millions of Dollars) | September 30, 2023 |  | September 30, 2022 |  | September 30, 2023 |  | September 30, 2022
Eversource | $ | 53.7 |  |  | $ | 52.9 |  |  | $ | 153.4 |  |  | $ | 146.0 |
CL&P | 50.2 |  |  | 49.2 |  |  | 132.2 |  |  | 126.0

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 September 30, 2023 |  | As of September 30, 2022
Eversource | $ | 462.4 |  |  | $ | 394.1 |
CL&P | 86.3 |  |  | 96.7 |
NSTAR Electric | 135.9 |  |  | 94.5 |
PSNH | 71.9 |  |  | 49.7 |

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

| As of September 30, 2023 |  | As of December 31, 2022
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Cash and Cash Equivalents as reported on the Balance Sheets | $ | 78.8 |  |  | $ | 9.8 |  |  | $ | 6.0 |  |  | $ | 33.9 |  |  | $ | 374.6 |  |  | $ | 11.3 |  |  | $ | 327.7 |  |  | $ | 0.1 |
Restricted cash included in: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Special Deposits | 68.4 |  |  | 9.1 |  |  | 8.8 |  |  | 18.2 |  |  | 102.2 |  |  | 8.8 |  |  | 17.5 |  |  | 33.1 |
Marketable Securities | 16.2 |  |  | — |  |  | — |  |  | — |  |  | 25.4 |  |  | 0.2 |  |  | 0.1 |  |  | 0.4 |
Other Long-Term Assets | 17.5 |  |  | — |  |  | — |  |  | 3.2 |  |  | 19.6 |  |  | — |  |  | — |  |  | 3.2 |
Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows | $ | 180.9 |  |  | $ | 18.9 |  |  | $ | 14.8 |  |  | $ | 55.3 |  |  | $ | 521.8 |  |  | $ | 20.3 |  |  | $ | 345.3 |  |  | $ | 36.8 |

Special Deposits represent cash collections related to the PSNH RRB customer charges that are held in trust, required ISO-NE cash deposits, cash held in escrow accounts, and CYAPC and YAEC cash balances. Special Deposits are included in Current Assets on the balance sheets. As of both September 30, 2023 and December 31, 2022, restricted cash included in Marketable Securities represented restricted trusts to fund CYAPC and YAEC's spent nuclear fuel storage obligations. As of December 31, 2022, restricted cash included in Marketable Securities also included money market funds held in trusts to fund certain non-qualified executive benefits.
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 included $20.0 million recorded as short-term in Special Deposits as of both September 30, 2023 and December 31, 2022, and $14.3 million and $15.9 million recorded in Other Long-Term Assets on the balance sheets as of September 30, 2023 and December 31, 2022, respectively.
23

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 September 30, 2023 |  | As of December 31, 2022
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Storm Costs, Net | $ | 1,700.6 |  |  | $ | 882.7 |  |  | $ | 553.9 |  |  | $ | 264.0 |  |  | $ | 1,379.1 |  |  | $ | 799.3 |  |  | $ | 484.4 |  |  | $ | 95.4 |
Regulatory Tracking Mechanisms | 1,173.3 |  |  | 254.3 |  |  | 473.4 |  |  | 166.1 |  |  | 1,075.3 |  |  | 216.8 |  |  | 391.5 |  |  | 73.7 |
Benefit Costs | 863.4 |  |  | 143.2 |  |  | 278.0 |  |  | 51.8 |  |  | 921.7 |  |  | 156.7 |  |  | 299.5 |  |  | 56.6 |
Income Taxes, Net | 879.6 |  |  | 504.5 |  |  | 125.7 |  |  | 17.6 |  |  | 853.3 |  |  | 491.1 |  |  | 115.6 |  |  | 16.0 |
Securitized Stranded Costs | 403.3 |  |  | — |  |  | — |  |  | 403.3 |  |  | 435.7 |  |  | — |  |  | — |  |  | 435.7 |
Goodwill-related | 268.3 |  |  | — |  |  | 230.4 |  |  | — |  |  | 281.0 |  |  | — |  |  | 241.2 |  |  | — |
Derivative Liabilities | 136.6 |  |  | 136.6 |  |  | — |  |  | — |  |  | 181.8 |  |  | 181.8 |  |  | — |  |  | — |
Asset Retirement Obligations | 135.0 |  |  | 37.8 |  |  | 70.9 |  |  | 4.7 |  |  | 127.9 |  |  | 35.9 |  |  | 68.2 |  |  | 4.4 |
Other Regulatory Assets | 296.5 |  |  | 23.5 |  |  | 96.3 |  |  | 9.0 |  |  | 322.5 |  |  | 26.2 |  |  | 114.0 |  |  | 14.4 |
Total Regulatory Assets | 5,856.6 |  |  | 1,982.6 |  |  | 1,828.6 |  |  | 916.5 |  |  | 5,578.3 |  |  | 1,907.8 |  |  | 1,714.4 |  |  | 696.2 |
Less: Current Portion | 1,507.9 |  |  | 383.7 |  |  | 638.5 |  |  | 177.1 |  |  | 1,335.5 |  |  | 314.1 |  |  | 492.8 |  |  | 102.2 |
Total Long-Term Regulatory Assets | $ | 4,348.7 |  |  | $ | 1,598.9 |  |  | $ | 1,190.1 |  |  | $ | 739.4 |  |  | $ | 4,242.8 |  |  | $ | 1,593.7 |  |  | $ | 1,221.6 |  |  | $ | 594.0 |

Regulatory Costs in Long-Term Assets: Eversource's regulated companies had $251.4 million (including $159.8 million for CL&P, $26.7 million for NSTAR Electric and $1.2 million for PSNH) and $210.8 million (including $135.9 million for CL&P, $19.8 million for NSTAR Electric and $1.0 million for PSNH) of additional regulatory costs as of September 30, 2023 and December 31, 2022, respectively, that were included in long-term assets on the balance sheets. These amounts represent incurred costs for which recovery has not yet been specifically approved by the applicable regulatory agency. However, based on regulatory policies or past precedent on similar costs, management believes it is probable that these costs will ultimately be approved and recovered from customers in rates.
As of September 30, 2023 and December 31, 2022, these regulatory costs included $85.6 million (including $65.6 million for CL&P and $9.6 million for NSTAR Electric) and $64.0 million (including $52.8 million for CL&P and $3.5 million for NSTAR Electric), respectively, of deferred uncollectible hardship costs. As of both September 30, 2023 and December 31, 2022, these regulatory costs also included incremental COVID-19 related non-tracked uncollectible expense deferred of $29.8 million at Eversource, $11.8 million at CL&P, and $2.2 million at NSTAR Electric.
Regulatory Liabilities: The components of regulatory liabilities were as follows:

| As of September 30, 2023 |  | As of December 31, 2022
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
EDIT due to Tax Cuts and Jobs Act of 2017 | $ | 2,568.6 |  |  | $ | 973.4 |  |  | $ | 915.2 |  |  | $ | 341.6 |  |  | $ | 2,619.3 |  |  | $ | 983.6 |  |  | $ | 944.3 |  |  | $ | 348.6 |
Cost of Removal | 680.8 |  |  | 154.9 |  |  | 418.3 |  |  | 16.0 |  |  | 670.6 |  |  | 130.8 |  |  | 405.3 |  |  | 14.7 |
Regulatory Tracking Mechanisms | 740.5 |  |  | 205.4 |  |  | 345.2 |  |  | 108.4 |  |  | 890.8 |  |  | 361.0 |  |  | 336.1 |  |  | 155.0 |
Deferred Portion of Non-Service Income Components of Pension, SERP and PBOP | 333.4 |  |  | 46.1 |  |  | 166.8 |  |  | 34.7 |  |  | 270.9 |  |  | 34.5 |  |  | 139.7 |  |  | 28.8 |
AFUDC - Transmission | 117.6 |  |  | 53.5 |  |  | 64.1 |  |  | — |  |  | 98.2 |  |  | 48.2 |  |  | 50.0 |  |  | — |
Benefit Costs | 43.9 |  |  | 0.5 |  |  | 21.4 |  |  | — |  |  | 55.4 |  |  | 0.7 |  |  | 31.4 |  |  | — |
Other Regulatory Liabilities | 261.4 |  |  | 30.4 |  |  | 72.6 |  |  | 4.9 |  |  | 215.9 |  |  | 40.6 |  |  | 14.5 |  |  | 6.5 |
Total Regulatory Liabilities | 4,746.2 |  |  | 1,464.2 |  |  | 2,003.6 |  |  | 505.6 |  |  | 4,821.1 |  |  | 1,599.4 |  |  | 1,921.3 |  |  | 553.6 |
Less: Current Portion | 724.4 |  |  | 155.9 |  |  | 416.0 |  |  | 114.6 |  |  | 890.8 |  |  | 336.0 |  |  | 373.2 |  |  | 162.0 |
Total Long-Term Regulatory Liabilities | $ | 4,021.8 |  |  | $ | 1,308.3 |  |  | $ | 1,587.6 |  |  | $ | 391.0 |  |  | $ | 3,930.3 |  |  | $ | 1,263.4 |  |  | $ | 1,548.1 |  |  | $ | 391.6 |

24

Regulatory Development:
PSNH Pole Acquisition Approval: On November 18, 2022, the NHPUC issued a decision that approved a proposed purchase agreement between PSNH and Consolidated Communications, in which PSNH would acquire both jointly-owned and solely-owned poles and pole assets. The NHPUC also authorized PSNH to recover certain expenses associated with the operation and maintenance of the transferred poles, pole inspections, and vegetation management expenses through a new cost recovery mechanism, the Pole Plant Adjustment Mechanism (PPAM), subject to consummation of the purchase agreement. The purchase agreement was finalized on May 1, 2023 for a purchase price of $23.3 million. Upon consummation of the purchase agreement, PSNH established a regulatory asset of $16.9 million for operation and maintenance expenses and vegetation management expenses associated with the purchased poles incurred from February 10, 2021 through April 30, 2023 that PSNH is authorized to collect through the PPAM regulatory tracking mechanism. The establishment of the PPAM regulatory asset resulted in a pre-tax benefit recorded in Amortization expense on the PSNH statement of income in the second quarter of 2023.
3. PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION
The following tables summarize property, plant and equipment by asset category:

Eversource | As of September 30, 2023 |  | As of December 31, 2022
(Millions of Dollars) |
Distribution - Electric | $ | 19,238.3 |  |  | $ | 18,326.2 |
Distribution - Natural Gas | 7,754.4 |  |  | 7,443.8 |
Transmission - Electric | 14,233.1 |  |  | 13,709.3 |
Distribution - Water | 2,203.6 |  |  | 2,112.6 |
Solar | 200.8 |  |  | 200.8 |
Utility | 43,630.2 |  |  | 41,792.7 |
Other (1) | 1,959.2 |  |  | 1,738.1 |
Property, Plant and Equipment, Gross | 45,589.4 |  |  | 43,530.8 |
Less: Accumulated Depreciation |  |  |
Utility | (9,518.6) |  |  | (9,167.4) |
Other | (823.0) |  |  | (706.1) |
Total Accumulated Depreciation | (10,341.6) |  |  | (9,873.5) |
Property, Plant and Equipment, Net | 35,247.8 |  |  | 33,657.3 |
Construction Work in Progress | 3,270.5 |  |  | 2,455.5 |
Total Property, Plant and Equipment, Net | $ | 38,518.3 |  |  | $ | 36,112.8 |

| As of September 30, 2023 |  | As of December 31, 2022
(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH |  | CL&P |  | NSTAR Electric |  | PSNH
Distribution - Electric | $ | 7,717.0 |  |  | $ | 8,816.5 |  |  | $ | 2,745.1 |  |  | $ | 7,370.1 |  |  | $ | 8,410.0 |  |  | $ | 2,586.4 |
Transmission - Electric | 6,345.8 |  |  | 5,536.6 |  |  | 2,352.4 |  |  | 6,165.1 |  |  | 5,333.8 |  |  | 2,212.0 |
Solar | — |  |  | 200.8 |  |  | — |  |  | — |  |  | 200.8 |  |  | — |
Property, Plant and Equipment, Gross | 14,062.8 |  |  | 14,553.9 |  |  | 5,097.5 |  |  | 13,535.2 |  |  | 13,944.6 |  |  | 4,798.4 |
Less: Accumulated Depreciation | (2,659.0) |  |  | (3,535.5) |  |  | (974.2) |  |  | (2,567.1) |  |  | (3,381.2) |  |  | (912.3) |
Property, Plant and Equipment, Net | 11,403.8 |  |  | 11,018.4 |  |  | 4,123.3 |  |  | 10,968.1 |  |  | 10,563.4 |  |  | 3,886.1 |
Construction Work in Progress | 632.2 |  |  | 1,390.8 |  |  | 309.7 |  |  | 498.9 |  |  | 1,063.6 |  |  | 174.1 |
Total Property, Plant and Equipment, Net | $ | 12,036.0 |  |  | $ | 12,409.2 |  |  | $ | 4,433.0 |  |  | $ | 11,467.0 |  |  | $ | 11,627.0 |  |  | $ | 4,060.2 |

(1) These assets are primarily comprised of computer software, hardware and equipment at Eversource Service and buildings at The Rocky River Realty Company.
4. DERIVATIVE INSTRUMENTS
The electric and natural gas companies purchase and procure energy and energy-related products, which are subject to price volatility, for their customers. The costs associated with supplying energy to customers are recoverable from customers in future rates. These regulated companies manage the risks associated with the price volatility of energy and energy-related products through the use of derivative and non-derivative contracts. Many of the derivative contracts meet the definition of, and are designated as, normal and qualify for accrual accounting under the applicable accounting guidance. The costs and benefits of derivative contracts that meet the definition of normal are recognized in Operating Expenses on the statements of income as electricity or natural gas is delivered.
Derivative contracts that are not designated as normal are recorded at fair value as current or long-term Derivative Assets or Derivative Liabilities on the balance sheets. For the electric and natural gas companies, regulatory assets or regulatory liabilities are recorded to offset the fair values of derivatives, as contract settlement amounts are recovered from, or refunded to, customers in their respective energy supply rates.
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The gross fair values of derivative assets and liabilities with the same counterparty are offset and reported as net Derivative Assets or Derivative Liabilities, with current and long-term portions, on the balance sheets. The following table presents the gross fair values of contracts, categorized by risk type, and the net amounts recorded as current or long-term derivative assets or liabilities:

|  |  | As of September 30, 2023 |  | As of December 31, 2022
CL&P (Millions of Dollars) | Fair Value Hierarchy |  | Commodity Supply and Price Risk Management |  | Netting (1) |  | Net Amount Recorded as a Derivative |  | Commodity Supply and Price Risk Management |  | Netting (1) |  | Net Amount Recorded as a Derivative
Current Derivative Assets | Level 3 |  | $ | 16.9 |  |  | $ | (0.5) |  |  | $ | 16.4 |  |  | $ | 16.3 |  |  | $ | (0.5) |  |  | $ | 15.8 |
Long-Term Derivative Assets | Level 3 |  | 17.0 |  |  | (0.5) |  |  | 16.5 |  |  | 28.8 |  |  | (0.9) |  |  | 27.9 |
Current Derivative Liabilities | Level 3 |  | (84.2) |  |  | — |  |  | (84.2) |  |  | (81.6) |  |  | — |  |  | (81.6) |
Long-Term Derivative Liabilities | Level 3 |  | (85.3) |  |  | — |  |  | (85.3) |  |  | (143.9) |  |  | — |  |  | (143.9) |

(1) Amounts represent derivative assets and liabilities that Eversource elected to record net on the balance sheets. These amounts are subject to master netting agreements or similar agreements for which the right of offset exists.
Derivative Contracts at Fair Value with Offsetting Regulatory Amounts
Commodity Supply and Price Risk Management: As required by regulation, CL&P, along with UI, has capacity-related contracts with generation facilities. CL&P has a sharing agreement with UI, with 80 percent of the costs or benefits of each contract borne by or allocated to CL&P and 20 percent borne by or allocated to UI. The combined capacities of these contracts as of both September 30, 2023 and December 31, 2022 were 674 MW. The capacity contracts extend through 2026 and obligate both CL&P and UI to make or receive payments on a monthly basis to or from the generation facilities based on the difference between a set capacity price and the capacity market price received in the ISO-NE capacity markets.
Fair Value Measurements of Derivative Instruments
The fair value of derivative contracts classified as Level 3 utilizes both significant observable and unobservable inputs. The fair value is modeled using income techniques, such as discounted cash flow valuations adjusted for assumptions related to exit price. Valuations of derivative contracts using a discounted cash flow methodology include assumptions regarding the timing and likelihood of scheduled payments and also reflect non-performance risk, including credit, using the default probability approach based on the counterparty's credit rating for assets and the Company's credit rating for liabilities. Significant observable inputs for valuations of these contracts include energy-related product prices in future years for which quoted prices in an active market exist. Valuations incorporate estimates of premiums or discounts that would be required by a market participant to arrive at an exit price, using historical market transactions adjusted for the terms of the contract. Fair value measurements categorized in Level 3 of the fair value hierarchy are prepared by individuals with expertise in valuation techniques, pricing of energy-related products, and accounting requirements.
Exit price premiums of 1.3 percent through 5.5 percent, or a weighted average of 4.5 percent, are Level 3 significant unobservable inputs applied to these contracts and reflect the uncertainty and illiquidity premiums that would be required based on the most recent market activity available for similar type contracts. The risk premium was weighted by the relative fair value of the net derivative instruments.
As of December 31, 2022, Level 3 unobservable inputs also utilized in the valuation of CL&P’s capacity-related related contracts included forward reserve prices of $0.44 per kW-Month through $0.50 per kW-Month, or a weighted average of $0.47 per kW-Month, over the period 2023 through 2024. As of September 30, 2023, these forward reserve prices are now observable.
Significant increases or decreases in future capacity or forward reserve prices in isolation would decrease or increase, respectively, the fair value of the derivative liability. Any increases in risk premiums would increase the fair value of the derivative liability. Changes in these fair values are recorded as a regulatory asset or liability and do not impact net income. The following table presents changes in the Level 3 category of derivative assets and derivative liabilities measured at fair value on a recurring basis. The derivative assets and liabilities are presented on a net basis.

CL&P | For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Millions of Dollars) | 2023 |  | 2022 |  | 2023 |  | 2022
Derivatives, Net: |  |  |  |  |  |  |
Fair Value as of Beginning of Period | $ | (152.1) |  |  | $ | (213.3) |  |  | $ | (181.8) |  |  | $ | (249.2) |
Net Realized/Unrealized (Losses)/Gains Included in Regulatory Assets | (1.5) |  |  | 2.4 |  |  | (1.6) |  |  | 11.2 |
Settlements | 17.0 |  |  | 15.0 |  |  | 46.8 |  |  | 42.1 |
Fair Value as of End of Period | $ | (136.6) |  |  | $ | (195.9) |  |  | $ | (136.6) |  |  | $ | (195.9) |

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 these 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.
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Equity Securities: Unrealized gains and losses on equity securities held in Eversource's non-qualified executive benefit trust are recorded in Other Income, Net on the statements of income. The fair value of these equity securities as of December 31, 2022 was $20.0 million. These equity securities were sold during 2023 and resulted in a $1.1 million gain recorded in Other Income, Net for the nine months ended September 30, 2023. For the three and nine months ended September 30, 2022, there was $1.5 million and $10.6 million of unrealized losses, respectively, recorded in Other Income, Net that related to equity securities still held at the reporting date.
Eversource's equity securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of $168.3 million and $170.1 million as of September 30, 2023 and December 31, 2022, respectively. Unrealized gains and losses for these spent nuclear fuel trusts are subject to regulatory accounting treatment and are recorded in Marketable Securities with the corresponding offset to long-term liabilities on the balance sheets, with no impact on the statements of income.
Available-for-Sale Debt Securities: The following is a summary of the available-for-sale debt securities:

| As of September 30, 2023 |  | As of December 31, 2022
Eversource (Millions of Dollars) | Amortized Cost |  | Pre-Tax Unrealized Gains |  | Pre-Tax Unrealized Losses |  | Fair Value |  | Amortized Cost |  | Pre-Tax Unrealized Gains |  | Pre-Tax Unrealized Losses |  | Fair Value
Debt Securities | $ | 173.0 |  |  | $ | 0.3 |  |  | $ | (11.0) |  |  | $ | 162.3 |  |  | $ | 201.6 |  |  | $ | 0.1 |  |  | $ | (16.2) |  |  | $ | 185.5 |

Unrealized gains and losses on available-for-sale debt securities held in Eversource's non-qualified executive benefit trust are recorded in Accumulated Other Comprehensive Income, excluding amounts related to credit losses or losses on securities intended to be sold, which are recorded in Other Income, Net. There was $1.2 million of realized losses recorded on securities sold for the nine months ended September 30, 2023 that were reclassified out of Accumulated Other Comprehensive Income and recorded in Other Income, Net. There have been no credit losses for the three and nine months ended September 30, 2023 and 2022, and no allowance for credit losses as of September 30, 2023. Factors considered in determining whether a credit loss exists include adverse conditions specifically affecting the issuer, the payment history, ratings and rating changes of the security, and the severity of the impairment. For asset-backed debt securities, underlying collateral and expected future cash flows are also evaluated. Debt securities included in Eversource's non-qualified benefit trust portfolio are investment-grade bonds with a lower default risk based on their credit quality.
Eversource's debt securities also include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts in the amounts of $162.2 million and $163.2 million as of September 30, 2023 and December 31, 2022, respectively. Unrealized gains and losses for available-for-sale debt securities included in the CYAPC and YAEC spent nuclear fuel trusts are subject to regulatory accounting treatment and are recorded in Marketable Securities with the corresponding offset to long-term liabilities on the balance sheets, with no impact on the statements of income. Pre-tax unrealized gains and losses as of September 30, 2023 and December 31, 2022 primarily relate to the debt securities included in CYAPC's and YAEC's spent nuclear fuel trusts.
As of September 30, 2023, the contractual maturities of available-for-sale debt securities were as follows:

Eversource (Millions of Dollars) | Amortized Cost |  | Fair Value
Less than one year (1) | $ | 19.0 |  |  | $ | 19.4 |
One to five years | 29.9 |  |  | 29.2 |
Six to ten years | 41.7 |  |  | 39.9 |
Greater than ten years | 82.4 |  |  | 73.8 |
Total Debt Securities | $ | 173.0 |  |  | $ | 162.3 |

(1) Amounts in the Less than one year category include securities in the CYAPC and YAEC spent nuclear fuel trusts, which are restricted and are classified in long-term Marketable Securities on the balance sheets.
Realized Gains and Losses: Realized gains and losses are recorded in Other Income, Net for Eversource's benefit trust and are offset in long-term liabilities for CYAPC and YAEC. Eversource utilizes the specific identification basis method for the Eversource non-qualified benefit trust, and the average cost basis method for the CYAPC and YAEC spent nuclear fuel trusts to compute the realized gains and losses on the sale of marketable securities.
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Fair Value Measurements: The following table presents the marketable securities recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy:

Eversource (Millions of Dollars) | As of September 30, 2023 |  | As of December 31, 2022
Level 1: |  |  |
Mutual Funds and Equities | $ | 168.3 |  |  | $ | 190.1 |
Money Market Funds | 16.2 |  |  | 25.4 |
Total Level 1 | $ | 184.5 |  |  | $ | 215.5 |
Level 2: |  |  |
U.S. Government Issued Debt Securities (Agency and Treasury) | $ | 86.1 |  |  | $ | 82.3 |
Corporate Debt Securities | 34.1 |  |  | 46.1 |
Asset-Backed Debt Securities | 5.9 |  |  | 8.6 |
Municipal Bonds | 9.3 |  |  | 12.7 |
Other Fixed Income Securities | 10.7 |  |  | 10.4 |
Total Level 2 | $ | 146.1 |  |  | $ | 160.1 |
Total Marketable Securities | $ | 330.6 |  |  | $ | 375.6 |

U.S. government issued debt securities are valued using market approaches that incorporate transactions for the same or similar bonds and adjustments for yields and maturity dates. Corporate debt securities are valued using a market approach, utilizing recent trades of the same or similar instruments and also incorporating yield curves, credit spreads and specific bond terms and conditions. Asset-backed debt securities include collateralized mortgage obligations, commercial mortgage backed securities, and securities collateralized by auto loans, credit card loans or receivables. Asset-backed debt securities are valued using recent trades of similar instruments, prepayment assumptions, yield curves, issuance and maturity dates, and tranche information. Municipal bonds are valued using a market approach that incorporates reported trades and benchmark yields. Other fixed income securities are valued using pricing models, quoted prices of securities with similar characteristics, and discounted cash flows.
6. SHORT-TERM AND LONG-TERM DEBT
Short-Term Debt - Commercial Paper Programs and Credit Agreements: Eversource parent has a $2.00 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas, EGMA and Aquarion Water Company of Connecticut are parties to a five-year $2.00 billion revolving credit facility, which terminates on October 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, and serves to backstop NSTAR Electric's $650 million commercial paper program.
The amount of borrowings outstanding and available under the commercial paper programs were as follows:

| Borrowings Outstanding as of |  | Available Borrowing Capacity as of |  | Weighted-Average Interest Rate as of
| September 30, 2023 |  | December 31, 2022 |  | September 30, 2023 |  | December 31, 2022 |  | September 30, 2023 |  | December 31, 2022
(Millions of Dollars) |  |  |  |  |
Eversource Parent Commercial Paper Program | $ | 1,320.3 |  |  | $ | 1,442.2 |  |  | $ | 679.7 |  |  | $ | 557.8 |  |  | 5.53 | % |  | 4.63 | %
NSTAR Electric Commercial Paper Program | 209.5 |  |  | — |  |  | 440.5 |  |  | 650.0 |  |  | 5.35 | % |  | — | %

There were no borrowings outstanding on the revolving credit facilities as of September 30, 2023 or December 31, 2022.
CL&P and PSNH have uncommitted line of credit agreements totaling $375 million and $250 million, respectively, which will expire in 2024. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of September 30, 2023.
Amounts outstanding under the commercial paper programs are included in Notes Payable and classified in current liabilities on the Eversource and NSTAR Electric balance sheets, as all borrowings are outstanding for no more than 364 days at one time.
Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of September 30, 2023, there were intercompany loans from Eversource parent to CL&P of $213.4 million and to PSNH of $0.1 million. As of December 31, 2022, there were intercompany loans from Eversource parent to PSNH of $173.3 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time.
Sources and Uses of Cash: The Company expects the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.
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Availability under Long-Term Debt Issuance Authorizations: On June 7, 2023, PURA approved Yankee Gas’ request for authorization to issue up to $350 million in long-term debt through December 31, 2024.
Long-Term Debt Issuances and Repayments: The following table summarizes long-term debt issuances and repayments:

(Millions of Dollars) | Interest Rate |  | Issuance/(Repayment) |  | Issue Date or Repayment Date |  | Maturity Date |  | Use of Proceeds for Issuance/ Repayment Information
CL&P 2023 Series A First Mortgage Bonds | 5.25 | % |  | $ | 500.0 |  |  | January 2023 |  | January 2053 |  | Repaid 2013 Series A Bonds at maturity and short-term debt, and paid capital expenditures and working capital
CL&P 2013 Series A First Mortgage Bonds | 2.50 | % |  | (400.0) |  |  | January 2023 |  | January 2023 |  | Paid at maturity
CL&P 2023 Series B First Mortgage Bonds | 4.90 | % |  | 300.0 |  |  | July 2023 |  | July 2033 |  | Repaid short-term debt, paid capital expenditures and working capital
NSTAR Electric 2023 Debentures | 5.60 | % |  | 150.0 |  |  | September 2023 |  | October 2028 |  | Repay Series G Senior Notes at maturity and short-term debt and for general corporate purposes
PSNH Series W First Mortgage Bonds | 5.15 | % |  | 300.0 |  |  | January 2023 |  | January 2053 |  | Repaid short-term debt, paid capital expenditures and working capital
PSNH Series X First Mortgage Bonds | 5.35 | % |  | 300.0 |  |  | September 2023 |  | October 2033 |  | Repaid Series S Bonds at maturity and for general corporate purposes
PSNH Series S First Mortgage Bonds | 3.50 | % |  | (325.0) |  |  | November 2023 |  | November 2023 |  | Paid at maturity
Eversource Parent Series Z Senior Notes | 5.45 | % |  | 750.0 |  |  | March 2023 |  | March 2028 |  | Repaid Series F Senior Notes at maturity and short-term debt
Eversource Parent Series F Senior Notes | 2.80 | % |  | (450.0) |  |  | May 2023 |  | May 2023 |  | Paid at maturity
Eversource Parent Series Z Senior Notes | 5.45 | % |  | 550.0 |  |  | May 2023 |  | March 2028 |  | Repay Series T Senior Notes and Series N Senior Notes at maturity and short-term debt
Eversource Parent Series AA Senior Notes | 4.75 | % |  | 450.0 |  |  | May 2023 |  | May 2026 |  | Repay Series T Senior Notes and Series N Senior Notes at maturity and short-term debt
Eversource Parent Series BB Senior Notes | 5.125 | % |  | 800.0 |  |  | May 2023 |  | May 2033 |  | Repay Series T Senior Notes and Series N Senior Notes at maturity and short-term debt
Eversource Parent Variable Rate Series T Senior Notes | SOFR plus 0.25% |  | (350.0) |  |  | August 2023 |  | August 2023 |  | Paid at maturity
Yankee Gas Series V First Mortgage Bonds | 5.51 | % |  | 170.0 |  |  | August 2023 |  | August 2030 |  | Repaid short-term debt and general corporate purposes
Aquarion Water Company of Connecticut Senior Notes | 5.89 | % |  | 50.0 |  |  | September 2023 |  | October 2043 |  | Repaid existing indebtedness, paid capital expenditures and general corporate purposes

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 September 30, 2023 |  | As of December 31, 2022
Restricted Cash - Current Portion (included in Current Assets) | $ | 16.6 |  |  | $ | 32.4 |
Restricted Cash - Long-Term Portion (included in Other Long-Term Assets) | 3.2 |  |  | 3.2 |
Securitized Stranded Cost (included in Regulatory Assets) | 403.3 |  |  | 435.7 |
Other Regulatory Liabilities (included in Regulatory Liabilities) | 6.7 |  |  | 6.0 |
Accrued Interest (included in Other Current Liabilities) | 2.5 |  |  | 6.9 |
Rate Reduction Bonds - Current Portion | 43.2 |  |  | 43.2 |
Rate Reduction Bonds - Long-Term Portion | 367.3 |  |  | 410.5 |

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(Millions of Dollars) PSNH Income Statements: | For the Three Months Ended |  | For the Nine Months Ended
September 30, 2023 |  | September 30, 2022 |  | September 30, 2023 |  | September 30, 2022
Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net) | $ | 10.8 |  |  | $ | 10.8 |  |  | $ | 32.4 |  |  | $ | 32.4 |
Interest Expense on RRB Principal (included in Interest Expense) | 3.9 |  |  | 4.2 |  |  | 11.9 |  |  | 12.9 |

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 September 30, 2023 |  | For the Three Months Ended September 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 |  |  | $ | 1.0 |  |  | $ | 1.9 |  |  | $ | 0.4 |  |  | $ | 0.3 |  |  | $ | 0.2 |
Interest Cost | 63.4 |  |  | 12.6 |  |  | 13.5 |  |  | 6.8 |  |  | 8.5 |  |  | 1.5 |  |  | 2.3 |  |  | 0.9 |
Expected Return on Plan Assets | (116.3) |  |  | (23.5) |  |  | (28.4) |  |  | (12.3) |  |  | (19.3) |  |  | (2.3) |  |  | (9.2) |  |  | (1.4) |
Actuarial Loss | 10.9 |  |  | 0.5 |  |  | 4.0 |  |  | 0.4 |  |  | — |  |  | — |  |  | — |  |  | — |
Prior Service Cost/(Credit) | 0.3 |  |  | — |  |  | 0.1 |  |  | — |  |  | (5.4) |  |  | 0.2 |  |  | (4.2) |  |  | 0.1 |
Settlement Loss | 8.7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Total Net Periodic Benefit Plan Income | $ | (22.3) |  |  | $ | (7.3) |  |  | $ | (8.9) |  |  | $ | (4.1) |  |  | $ | (14.3) |  |  | $ | (0.2) |  |  | $ | (10.8) |  |  | $ | (0.2) |
Intercompany Expense/(Income) Allocations | N/A |  | $ | 0.8 |  |  | $ | 0.9 |  |  | $ | 0.3 |  |  | N/A |  | $ | (0.5) |  |  | $ | (0.5) |  |  | $ | (0.2) |
| Pension and SERP |  | PBOP
| For the Nine Months Ended September 30, 2023 |  | For the Nine Months Ended September 30, 2023
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Service Cost | $ | 32.4 |  |  | $ | 9.2 |  |  | $ | 5.9 |  |  | $ | 3.2 |  |  | $ | 5.7 |  |  | $ | 1.0 |  |  | $ | 0.9 |  |  | $ | 0.6 |
Interest Cost | 190.6 |  |  | 37.9 |  |  | 40.5 |  |  | 20.4 |  |  | 25.4 |  |  | 4.6 |  |  | 6.9 |  |  | 2.7 |
Expected Return on Plan Assets | (348.7) |  |  | (70.6) |  |  | (85.3) |  |  | (37.1) |  |  | (57.9) |  |  | (7.0) |  |  | (27.7) |  |  | (4.2) |
Actuarial Loss | 35.0 |  |  | 1.9 |  |  | 12.9 |  |  | 1.2 |  |  | — |  |  | — |  |  | — |  |  | — |
Prior Service Cost/(Credit) | 0.9 |  |  | — |  |  | 0.3 |  |  | — |  |  | (16.2) |  |  | 0.8 |  |  | (12.7) |  |  | 0.3 |
Settlement Loss | 12.4 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Total Net Periodic Benefit Plan Income | $ | (77.4) |  |  | $ | (21.6) |  |  | $ | (25.7) |  |  | $ | (12.3) |  |  | $ | (43.0) |  |  | $ | (0.6) |  |  | $ | (32.6) |  |  | $ | (0.6) |
Intercompany Income Allocations | N/A |  | $ | (1.8) |  |  | $ | (1.2) |  |  | $ | (0.3) |  |  | N/A |  | $ | (1.4) |  |  | $ | (1.6) |  |  | $ | (0.5) |

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| Pension and SERP |  | PBOP
| For the Three Months Ended September 30, 2022 |  | For the Three Months Ended September 30, 2022
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Service Cost | $ | 17.5 |  |  | $ | 4.7 |  |  | $ | 3.4 |  |  | $ | 1.7 |  |  | $ | 2.9 |  |  | $ | 0.5 |  |  | $ | 0.5 |  |  | $ | 0.3 |
Interest Cost | 38.6 |  |  | 7.8 |  |  | 8.2 |  |  | 4.2 |  |  | 5.0 |  |  | 0.9 |  |  | 1.3 |  |  | 0.5 |
Expected Return on Plan Assets | (130.7) |  |  | (26.5) |  |  | (32.1) |  |  | (14.0) |  |  | (22.5) |  |  | (2.8) |  |  | (10.6) |  |  | (1.7) |
Actuarial Loss | 28.4 |  |  | 4.0 |  |  | 8.1 |  |  | 1.9 |  |  | — |  |  | — |  |  | — |  |  | — |
Prior Service Cost/(Credit) | 0.4 |  |  | — |  |  | 0.1 |  |  | — |  |  | (5.4) |  |  | 0.3 |  |  | (4.2) |  |  | 0.1 |
Total Net Periodic Benefit Plan Income | $ | (45.8) |  |  | $ | (10.0) |  |  | $ | (12.3) |  |  | $ | (6.2) |  |  | $ | (20.0) |  |  | $ | (1.1) |  |  | $ | (13.0) |  |  | $ | (0.8) |
Intercompany Income Allocations | N/A |  | $ | (4.0) |  |  | $ | (3.2) |  |  | $ | (1.0) |  |  | N/A |  | $ | (0.9) |  |  | $ | (0.9) |  |  | $ | (0.3) |
| Pension and SERP |  | PBOP
| For the Nine Months Ended September 30, 2022 |  | For the Nine Months Ended September 30, 2022
(Millions of Dollars) | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH |  | Eversource |  | CL&P |  | NSTAR Electric |  | PSNH
Service Cost | $ | 52.7 |  |  | $ | 13.9 |  |  | $ | 10.4 |  |  | $ | 5.2 |  |  | $ | 8.7 |  |  | $ | 1.5 |  |  | $ | 1.5 |  |  | $ | 0.8 |
Interest Cost | 115.8 |  |  | 23.4 |  |  | 24.5 |  |  | 12.6 |  |  | 15.1 |  |  | 2.7 |  |  | 3.9 |  |  | 1.6 |
Expected Return on Plan Assets | (393.1) |  |  | (79.6) |  |  | (96.2) |  |  | (42.1) |  |  | (67.5) |  |  | (8.4) |  |  | (31.8) |  |  | (5.0) |
Actuarial Loss | 87.5 |  |  | 12.2 |  |  | 24.7 |  |  | 6.0 |  |  | — |  |  | — |  |  | — |  |  | — |
Prior Service Cost/(Credit) | 1.1 |  |  | — |  |  | 0.3 |  |  | — |  |  | (16.2) |  |  | 0.8 |  |  | (12.7) |  |  | 0.3 |
Total Net Periodic Benefit Plan Income | $ | (136.0) |  |  | $ | (30.1) |  |  | $ | (36.3) |  |  | $ | (18.3) |  |  | $ | (59.9) |  |  | $ | (3.4) |  |  | $ | (39.1) |  |  | $ | (2.3) |
Intercompany Income Allocations | N/A |  | $ | (11.9) |  |  | $ | (9.3) |  |  | $ | (2.7) |  |  | N/A |  | $ | (2.7) |  |  | $ | (2.7) |  |  | $ | (0.9) |

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

| As of September 30, 2023 |  | As of December 31, 2022
| Number of Sites |  | Reserve (in millions) |  | Number of Sites |  | Reserve (in millions)
Eversource | 63 |  |  | $ | 130.5 |  |  | 59 |  |  | $ | 122.6 |
CL&P | 14 |  |  | 12.6 |  |  | 13 |  |  | 13.9 |
NSTAR Electric | 12 |  |  | 5.4 |  |  | 10 |  |  | 3.4 |
PSNH | 8 |  |  | 7.7 |  |  | 8 |  |  | 6.1 |

The increase in the reserve balance was due primarily to the addition of one environmental site at NSTAR Gas, two additional environmental sites at NSTAR Electric, and changes in cost estimates at certain MGP sites at our natural gas companies and PSNH for which additional remediation will be required.
Included in the number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured natural gas from coal and other processes, which resulted in certain by-products remaining in the environment that may pose a potential risk to human health and the environment, for which Eversource may have potential liability. The reserve balances related to these former MGP sites were $120.5 million and $112.6 million as of September 30, 2023 and December 31, 2022, respectively, and related primarily to the natural gas business segment.
These reserve estimates are subjective in nature as they take into consideration several different remediation options at each specific site. The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource's, CL&P's, NSTAR Electric's and PSNH's responsibility for remediation or the extent of remediation required, recently enacted laws and regulations or changes in cost estimates due to certain economic factors. It is possible that new information or future developments could require a reassessment of the potential exposure to required environmental remediation. As this information becomes available, management will continue to assess the potential exposure and adjust the reserves accordingly.
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B. Guarantees and Indemnifications
In the normal course of business, Eversource parent provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric and PSNH, in the form of guarantees. Management does not anticipate a material impact to net income or cash flows as a result of these various guarantees and indemnifications.
Guarantees issued on behalf of unconsolidated entities, including equity method offshore wind investments, for which Eversource parent is the guarantor, are recorded at fair value as a liability on the balance sheet at the inception of the guarantee. Eversource regularly reviews performance risk under these guarantee arrangements, and in the event it becomes probable that Eversource parent will be required to perform under the guarantee, the amount of probable payment will be recorded. The fair value of guarantees issued on behalf of unconsolidated entities are recorded within Other Long-Term Liabilities on the balance sheet, and were $4.4 million and $4.2 million as of September 30, 2023 and December 31, 2022, respectively.
The following table summarizes Eversource parent's exposure to guarantees and indemnifications of its subsidiaries and affiliates to external parties, and primarily relates to its offshore wind business:

As of September 30, 2023
Company (Obligor) |  | Description |  | Maximum Exposure (in millions) |  | Expiration Dates
North East Offshore |  | Construction-related purchase agreements with third-party contractors (1) |  | $ | 705.8 |  |  | (1)
Sunrise Wind LLC |  | Construction-related purchase agreements with third-party contractors (2) |  | 823.3 |  |  | 2025 - 2028
Revolution Wind, LLC |  | Construction-related purchase agreements with third-party contractors (3) |  | 381.1 |  |  | 2024 - 2027
South Fork Wind, LLC |  | Construction-related purchase agreements with third-party contractors (4) |  | 55.5 |  |  | 2023 - 2026
Eversource Investment LLC |  | Funding and indemnification obligations of South Fork Wind (5) |  | 77.4 |  |  | (5)
South Fork Class B Member, LLC |  | Funding and indemnification obligations of South Fork Wind (6) |  | 77.4 |  |  | (6)
Eversource Investment LLC |  | Funding and indemnification obligations of North East Offshore (7) |  | 29.8 |  |  | (7)
South Fork Wind, LLC |  | Power Purchase Agreement Security (8) |  | 7.1 |  |  | (8)
Sunrise Wind LLC |  | OREC capacity production (9) |  | 11.0 |  |  | (9)
Bay State Wind LLC |  | Real estate purchase |  | 2.5 |  |  | 2024
South Fork Wind, LLC |  | Transmission interconnection |  | 1.2 |  |  | —
Eversource Investment LLC |  | Letters of Credit (10) |  | 15.2 |  |  | —
Eversource TEI LLC |  | South Fork Wind Tax Equity (11) |  | — |  |  | (11)
Various |  | Surety bonds (12) |  | 38.8 |  |  | 2023 - 2024
Eversource Service |  | Lease payments for real estate |  | 0.3 |  |  | 2024

(1) Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, North East Offshore (NEO), under which Eversource parent agreed to guarantee 50 percent of NEO’s performance of obligations under certain purchase agreements with third-party contractors, in an aggregate amount not to exceed $1.3 billion with an expiration date in 2025. Eversource parent also issued a separate guarantee to Ørsted on behalf of NEO, under which Eversource parent agreed to guarantee 50 percent of NEO’s payment obligations under certain offshore wind project construction-related agreements with Ørsted in an aggregate amount not to exceed $62.5 million and expiring upon full performance of the guaranteed obligation. Any amounts paid under this guarantee to Ørsted will count toward, but not increase, the maximum amount of the Funding Guarantee described in Note 7, below.
(2) Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guarantee Sunrise Wind LLC's performance of certain obligations, in an aggregate amount not to exceed $1.06 billion, in connection with construction-related purchase agreements. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging from March 2025 and October 2028 and (ii) full performance of the guaranteed obligations.
(3) Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, Revolution Wind, LLC, whereby Eversource parent will guarantee Revolution Wind, LLC's performance of certain obligations, in an aggregate amount not to exceed $546.4 million, in connection with construction-related purchase agreements. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging from May 2024 and November 2027 and (ii) full performance of the guaranteed obligations.
(4) Eversource parent issued guarantees on behalf of its 50 percent-owned affiliate, South Fork Wind, LLC, whereby Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations in connection with construction-related purchase agreements. Under these guarantees, Eversource parent will guarantee South Fork Wind, LLC's performance of certain obligations, in a total aggregate amount not to exceed $161.0 million. Eversource parent’s obligations under these guarantees expire upon the earlier of (i) dates ranging from October 2023 and August 2026 and (ii) full performance of the guaranteed obligations.
(5) Eversource parent issued a guarantee on behalf of its wholly-owned subsidiary Eversource Investment LLC (EI), which holds Eversource's investments in offshore wind-related equity method investments, whereby Eversource parent will guarantee EI’s performance of certain obligations, in an amount not to exceed $110.0 million, primarily in connection with capital expenditure funding obligations during the construction phase of the South Fork Wind project. Eversource parent obligations expire upon the full performance of the guaranteed obligations.
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(6) Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, South Fork Class B Member, LLC, whereby Eversource parent will guarantee South Fork Class B Member, LLC’s performance of certain obligations, in an amount not to exceed $499.5 million, primarily in connection with capital expenditure funding obligations during the construction phase of the South Fork Wind project. Eversource parent obligations expire upon the full performance of the guaranteed obligations.
(7) Eversource parent issued a guarantee (Funding Guarantee) on behalf of EI, under which Eversource parent agreed to guarantee certain funding obligations and certain indemnification payments of EI under the operating agreement of NEO, in an amount not to exceed $910 million. The guaranteed obligations include payment of EI's funding obligations during the construction phase of NEO’s underlying offshore wind projects and indemnification obligations associated with third party credit support for its investment in NEO. Eversource parent’s obligations under the Funding Guarantee expire upon the full performance of the guaranteed obligations.
(8) 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.
(9) Eversource parent issued a guarantee on behalf of its 50 percent-owned affiliate, Sunrise Wind LLC, whereby Eversource parent will guarantee Sunrise Wind LLC's performance of certain obligations, in an amount not to exceed $15.4 million, under the Offshore Wind Renewable Energy Certificate Purchase and Sale Agreement (the Agreement). The Agreement was executed by and between the New York State Energy Research and Development Authority (NYSERDA) and Sunrise Wind LLC. The guarantee expires upon the full performance of the guaranteed obligations.
(10) On September 16, 2020, 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. In January 2022, EI issued two letters of credit on behalf of South Fork Wind, LLC related to future decommissioning obligations of certain onshore transmission assets totaling $4.3 million. In June 2023, EI issued a letter of credit on behalf of Sunrise Wind LLC related to future environmental remediation in the amount of $9.9 million. In September 2023, EI issued a letter of credit on behalf of Revolution Wind, LLC related to onshore transmission construction in the amount of $1.0 million.
(11) 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 $528.4 million, primarily in connection with tax equity funding obligations during the construction phase of the South Fork Wind project. Eversource parent obligations expire upon the full performance of the guaranteed obligations.
(12) Surety bond expiration dates reflect termination dates, the majority of which will be renewed or extended. Certain surety bonds contain credit ratings triggers that would require Eversource parent to post collateral in the event that the unsecured debt credit ratings of Eversource parent are downgraded.
C. Spent Nuclear Fuel Obligations - Yankee Companies
CL&P, NSTAR Electric and PSNH have plant closure and fuel storage cost obligations to the Yankee Companies, which have each completed the physical decommissioning of their respective nuclear power facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies fund these costs through litigation proceeds received from the DOE and, to the extent necessary, through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. CL&P, NSTAR Electric and PSNH, in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies collect amounts that management believes are adequate to recover the remaining plant closure and fuel storage cost estimates for the respective plants. Management believes CL&P and NSTAR Electric will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers.
Spent Nuclear Fuel Litigation:
The Yankee Companies have filed complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to accept delivery of, and provide for a permanent facility to store, spent nuclear fuel pursuant to the terms of the 1983 spent fuel and high-level waste disposal contracts between the Yankee Companies and the DOE. The court previously awarded the Yankee Companies damages for Phases I, II, III and IV of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2016, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers.
DOE Phase V Damages - On March 25, 2021, each of the Yankee Companies filed a fifth set of lawsuits against the DOE in the Court of Federal Claims resulting from the DOE's failure to begin accepting spent nuclear fuel for disposal covering the years from 2017 to 2020. The Yankee Companies filed claims seeking monetary damages totaling $120.4 million for CYAPC, YAEC and MYAPC. Pursuant to a June 2, 2022 court order, the Yankee Companies were subsequently permitted to include monetary damages relating to the year 2021 in the DOE Phase V complaint. The Yankee Companies submitted a supplemental filing to include these costs of $33.1 million on June 8, 2022. The DOE Phase V trial is now expected to begin in 2024.
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D. FERC ROE Complaints
Four separate complaints were filed at the FERC by combinations of New England state attorneys general, state regulatory commissions, consumer advocates, consumer groups, municipal parties and other parties (collectively, the Complainants). In each of the first three complaints, filed on October 1, 2011, December 27, 2012, and July 31, 2014, respectively, the Complainants challenged the NETOs' base ROE of 11.14 percent that had been utilized since 2005 and sought an order to reduce it prospectively from the date of the final FERC order and for the separate 15-month complaint periods. In the fourth complaint, filed April 29, 2016, the Complainants challenged the NETOs' base ROE billed of 10.57 percent and the maximum ROE for transmission incentive (incentive cap) of 11.74 percent, asserting that these ROEs were unjust and unreasonable.
The ROE originally billed during the period October 1, 2011 (beginning of the first complaint period) through October 15, 2014 consisted of a base ROE of 11.14 percent and incentives up to 13.1 percent. On October 16, 2014, FERC issued Opinion No. 531-A and set the base ROE at 10.57 percent and the incentive cap at 11.74 percent for the first complaint period. This was also effective for all prospective billings to customers beginning October 16, 2014. This FERC order was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (the Court).
All amounts associated with the first complaint period have been refunded, which totaled $38.9 million (pre-tax and excluding interest) at Eversource and reflected both the base ROE and incentive cap prescribed by the FERC order. The refund consisted of $22.4 million for CL&P, $13.7 million for NSTAR Electric and $2.8 million for PSNH.
Eversource has recorded a reserve of $39.1 million (pre-tax and excluding interest) for the second complaint period as of both September 30, 2023 and December 31, 2022. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of both September 30, 2023 and December 31, 2022.
On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.
The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.
If the results of the illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order.
On November 21, 2019, FERC issued Opinion No. 569 affecting the two pending transmission ROE complaints against the Midcontinent ISO (MISO) transmission owners, in which FERC adopted a new methodology for determining base ROEs. Various parties sought rehearing. On December 23, 2019, the NETOs filed supplementary materials in the NETOs' four pending cases to respond to this new methodology because of the uncertainty of the applicability to the NETOs' cases. On May 21, 2020, the FERC issued its order in Opinion No. 569-A on the rehearing of the MISO transmission owners' cases, in which FERC again changed its methodology for determining the MISO transmission owners' base ROEs. On November 19, 2020, the FERC issued Opinion No. 569-B denying rehearing of Opinion No. 569-A and reaffirmed the methodology previously adopted in Opinion No. 569-A. The new methodology differs significantly from the methodology proposed by FERC in its October 16, 2018 order to determine the NETOs' base ROEs in its four pending cases. FERC Opinion Nos. 569-A and 569-B were appealed to the Court. On August 9, 2022, the Court issued its decision vacating MISO ROE FERC Opinion Nos. 569, 569-A and 569-B and remanded to FERC to reopen the proceedings. The Court found that FERC’s development of the new return methodology was arbitrary and capricious due to FERC’s failure to offer a reasonable explanation for its decision to reintroduce the risk-premium financial model in its new methodology for calculating a just and reasonable return. At this time, Eversource cannot predict how and when FERC will address the Court’s findings on the remand of the MISO FERC opinions or any potential associated impact on the NETOs’ four pending ROE complaint cases.
Given the significant uncertainty regarding the applicability of the FERC opinions in the MISO transmission owners’ two complaint cases to the NETOs’ pending four complaint cases, Eversource concluded that there is no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods at this time. As well, Eversource cannot reasonably estimate a range of loss for any of the four complaint proceedings at this time.
Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.
A change of 10 basis points to the base ROE used to establish the reserves would impact Eversource’s after-tax earnings by an average of approximately $3 million for each of the four 15-month complaint periods.
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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 September 30, 2023: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Preferred Stock Not Subject to Mandatory Redemption | $ | 155.6 |  |  | $ | 118.0 |  |  | $ | 116.2 |  |  | $ | 87.2 |  |  | $ | 43.0 |  |  | $ | 30.8 |  |  | $ | — |  |  | $ | — |
Long-Term Debt | 24,159.1 |  |  | 21,260.5 |  |  | 4,606.8 |  |  | 4,025.3 |  |  | 4,576.5 |  |  | 4,071.1 |  |  | 1,756.6 |  |  | 1,483.4 |
Rate Reduction Bonds | 410.5 |  |  | 381.6 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 410.5 |  |  | 381.6 |
As of December 31, 2022: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Preferred Stock Not Subject to Mandatory Redemption | $ | 155.6 |  |  | $ | 136.7 |  |  | $ | 116.2 |  |  | $ | 99.2 |  |  | $ | 43.0 |  |  | $ | 37.5 |  |  | $ | — |  |  | $ | — |
Long-Term Debt | 21,044.1 |  |  | 18,891.3 |  |  | 4,216.5 |  |  | 3,828.3 |  |  | 4,425.1 |  |  | 4,091.8 |  |  | 1,164.6 |  |  | 970.5 |
Rate Reduction Bonds | 453.7 |  |  | 424.7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 453.7 |  |  | 424.7 |

Derivative Instruments and Marketable Securities: Derivative instruments and investments in marketable securities are carried at fair value. For further information, see Note 4, "Derivative Instruments," and Note 5, "Marketable Securities," to the financial statements.
See Note 1C, "Summary of Significant Accounting Policies – Fair Value Measurements," for the fair value measurement policy and the fair value hierarchy.
11. ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS)
The changes in accumulated other comprehensive income/(loss) by component, net of tax, are as follows:

| For the Nine Months Ended September 30, 2023 |  | For the Nine Months Ended September 30, 2022
Eversource (Millions of Dollars) | Qualified Cash Flow Hedging Instruments |  | Unrealized Gains/(Losses) on Marketable Securities |  | Defined Benefit Plans |  | Total |  | Qualified Cash Flow Hedging Instruments |  | Unrealized Gains/(Losses) on Marketable Securities |  | Defined Benefit Plans |  | Total
Balance as of Beginning of Period | $ | (0.4) |  |  | $ | (1.2) |  |  | $ | (37.8) |  |  | $ | (39.4) |  |  | $ | (0.4) |  |  | $ | 0.4 |  |  | $ | (42.3) |  |  | $ | (42.3) |
OCI Before Reclassifications | — |  |  | — |  |  | 0.1 |  |  | 0.1 |  |  | — |  |  | (2.0) |  |  | (2.5) |  |  | (4.5) |
Amounts Reclassified from AOCI | — |  |  | 1.2 |  |  | 14.1 |  |  | 15.3 |  |  | — |  |  | — |  |  | 5.8 |  |  | 5.8 |
Net OCI | — |  |  | 1.2 |  |  | 14.2 |  |  | 15.4 |  |  | — |  |  | (2.0) |  |  | 3.3 |  |  | 1.3 |
Balance as of End of Period | $ | (0.4) |  |  | $ | — |  |  | $ | (23.6) |  |  | $ | (24.0) |  |  | $ | (0.4) |  |  | $ | (1.6) |  |  | $ | (39.0) |  |  | $ | (41.0) |

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. Defined benefit plan amounts reclassified from AOCI also include a settlement loss amortized into net periodic benefit plan expense/(income) for the nine months ended September 30, 2023. See Note 8, "Pension Benefits and Postretirement Benefits Other Than Pension," for further information.
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 |  | Issued as of
| Par Value |  | September 30, 2023 |  | December 31, 2022 |  | September 30, 2023 |  | December 31, 2022
Eversource | $ | 5 |  |  | 410,000,000 |  |  | 380,000,000 |  |  | 359,984,073 |  |  | 359,984,073 |
CL&P | $ | 10 |  |  | 24,500,000 |  |  | 24,500,000 |  |  | 6,035,205 |  |  | 6,035,205 |
NSTAR Electric | $ | 1 |  |  | 100,000,000 |  |  | 100,000,000 |  |  | 200 |  |  | 200 |
PSNH | $ | 1 |  |  | 100,000,000 |  |  | 100,000,000 |  |  | 301 |  |  | 301 |

35

Treasury Shares: As of September 30, 2023 and December 31, 2022, there were 10,708,298 and 11,540,218 Eversource common shares held as treasury shares, respectively. As of September 30, 2023 and December 31, 2022, there were 349,275,775 and 348,443,855 Eversource common shares outstanding, respectively.
Eversource issues treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan. Eversource also issued treasury shares for its October 2022 water business acquisition. The issuance of treasury shares represents a non-cash transaction, as the treasury shares were used to fulfill Eversource's obligations that require the issuance of common shares.
On May 3, 2023, shareholders voted to increase the authorized common shares from 380,000,000 shares to 410,000,000 shares.
13. COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS
Dividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for each of the three months ended September 30, 2023 and 2022 and $5.6 million for each of the nine months ended September 30, 2023 and 2022. These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of September 30, 2023 and December 31, 2022. On the Eversource balance sheets, Common Shareholders' Equity was fully attributable to Eversource parent and Noncontrolling Interest – Preferred Stock of Subsidiaries was fully attributable to the noncontrolling interest.
14. EARNINGS PER SHARE
Basic EPS is computed based upon the weighted average number of common shares outstanding during each period. Diluted EPS is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards as if they were converted into outstanding common shares. The dilutive effect of unvested RSU and performance share awards is calculated using the treasury stock method. RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. For the three and nine months ended September 30, 2023 and 2022, there were no antidilutive share awards excluded from the computation of diluted EPS.
The following table sets forth the components of basic and diluted EPS:

Eversource (Millions of Dollars, except share information) | For the Three Months Ended |  | For the Nine Months Ended
September 30, 2023 |  | September 30, 2022 |  | September 30, 2023 |  | September 30, 2022
Net Income Attributable to Common Shareholders | $ | 339.7 |  |  | $ | 349.4 |  |  | $ | 846.2 |  |  | $ | 1,084.7 |
Weighted Average Common Shares Outstanding: |  |  |  |  |  |  |
Basic | 349,704,155 |  |  | 347,297,411 |  |  | 349,461,219 |  |  | 346,115,823 |
Dilutive Effect | 147,814 |  |  | 465,282 |  |  | 270,101 |  |  | 457,278 |
Diluted | 349,851,969 |  |  | 347,762,693 |  |  | 349,731,320 |  |  | 346,573,101 |
Basic EPS | $ | 0.97 |  |  | $ | 1.01 |  |  | $ | 2.42 |  |  | $ | 3.13 |
Diluted EPS | $ | 0.97 |  |  | $ | 1.00 |  |  | $ | 2.42 |  |  | $ | 3.13 |

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

| For the Three Months Ended September 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 | $ | 1,375.9 |  |  | $ | 83.0 |  |  | $ | — |  |  | $ | 44.7 |  |  | $ | — |  |  | $ | — |  |  | $ | 1,503.6 |
Commercial | 764.1 |  |  | 33.7 |  |  | — |  |  | 19.6 |  |  | — |  |  | (1.1) |  |  | 816.3 |
Industrial | 94.5 |  |  | 30.2 |  |  | — |  |  | 1.2 |  |  | — |  |  | (4.8) |  |  | 121.1 |
Total Retail Tariff Sales Revenues | 2,234.5 |  |  | 146.9 |  |  | — |  |  | 65.5 |  |  | — |  |  | (5.9) |  |  | 2,441.0 |
Wholesale Transmission Revenues | — |  |  | — |  |  | 520.2 |  |  | — |  |  | — |  |  | (386.6) |  |  | 133.6 |
Wholesale Market Sales Revenues | 154.9 |  |  | 71.6 |  |  | — |  |  | 1.1 |  |  | — |  |  | — |  |  | 227.6 |
Other Revenues from Contracts with Customers | 20.9 |  |  | 1.3 |  |  | 4.8 |  |  | 2.0 |  |  | 394.7 |  |  | (392.4) |  |  | 31.3 |
Total Revenues from Contracts with Customers | 2,410.3 |  |  | 219.8 |  |  | 525.0 |  |  | 68.6 |  |  | 394.7 |  |  | (784.9) |  |  | 2,833.5 |
Alternative Revenue Programs | (43.8) |  |  | (2.4) |  |  | (33.6) |  |  | (0.3) |  |  | — |  |  | 31.9 |  |  | (48.2) |
Other Revenues | 4.8 |  |  | 0.9 |  |  | 0.2 |  |  | 0.3 |  |  | — |  |  | — |  |  | 6.2 |
Total Operating Revenues | $ | 2,371.3 |  |  | $ | 218.3 |  |  | $ | 491.6 |  |  | $ | 68.6 |  |  | $ | 394.7 |  |  | $ | (753.0) |  |  | $ | 2,791.5 |

36

| For the Nine Months Ended September 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 | $ | 3,982.1 |  |  | $ | 858.0 |  |  | $ | — |  |  | $ | 112.6 |  |  | $ | — |  |  | $ | — |  |  | $ | 4,952.7 |
Commercial | 2,244.7 |  |  | 483.6 |  |  | — |  |  | 53.2 |  |  | — |  |  | (3.4) |  |  | 2,778.1 |
Industrial | 268.5 |  |  | 141.7 |  |  | — |  |  | 3.4 |  |  | — |  |  | (14.6) |  |  | 399.0 |
Total Retail Tariff Sales Revenues | 6,495.3 |  |  | 1,483.3 |  |  | — |  |  | 169.2 |  |  | — |  |  | (18.0) |  |  | 8,129.8 |
Wholesale Transmission Revenues | — |  |  | — |  |  | 1,358.2 |  |  | — |  |  | — |  |  | (1,015.6) |  |  | 342.6 |
Wholesale Market Sales Revenues | 484.4 |  |  | 160.5 |  |  | — |  |  | 2.9 |  |  | — |  |  | — |  |  | 647.8 |
Other Revenues from Contracts with Customers | 60.1 |  |  | 3.9 |  |  | 14.1 |  |  | 6.1 |  |  | 1,217.3 |  |  | (1,210.7) |  |  | 90.8 |
Total Revenues from Contracts with Customers | 7,039.8 |  |  | 1,647.7 |  |  | 1,372.3 |  |  | 178.2 |  |  | 1,217.3 |  |  | (2,244.3) |  |  | 9,211.0 |
Alternative Revenue Programs | (40.7) |  |  | 21.9 |  |  | 57.6 |  |  | (2.0) |  |  | — |  |  | (50.8) |  |  | (14.0) |
Other Revenues | 15.2 |  |  | 3.0 |  |  | 0.5 |  |  | 0.8 |  |  | — |  |  | — |  |  | 19.5 |
Total Operating Revenues | $ | 7,014.3 |  |  | $ | 1,672.6 |  |  | $ | 1,430.4 |  |  | $ | 177.0 |  |  | $ | 1,217.3 |  |  | $ | (2,295.1) |  |  | $ | 9,216.5 |

| For the Three Months Ended September 30, 2022
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 1,492.9 |  |  | $ | 94.7 |  |  | $ | — |  |  | $ | 45.7 |  |  | $ | — |  |  | $ | — |  |  | $ | 1,633.3 |
Commercial | 890.5 |  |  | 76.7 |  |  | — |  |  | 18.5 |  |  | — |  |  | (1.7) |  |  | 984.0 |
Industrial | 105.6 |  |  | 33.6 |  |  | — |  |  | 1.3 |  |  | — |  |  | (5.2) |  |  | 135.3 |
Total Retail Tariff Sales Revenues | 2,489.0 |  |  | 205.0 |  |  | — |  |  | 65.5 |  |  | — |  |  | (6.9) |  |  | 2,752.6 |
Wholesale Transmission Revenues | — |  |  | — |  |  | 520.3 |  |  | — |  |  | 29.9 |  |  | (416.3) |  |  | 133.9 |
Wholesale Market Sales Revenues | 317.1 |  |  | 22.7 |  |  | — |  |  | 1.1 |  |  | — |  |  | — |  |  | 340.9 |
Other Revenues from Contracts with Customers | 17.3 |  |  | 0.6 |  |  | 3.4 |  |  | 2.1 |  |  | 313.6 |  |  | (311.9) |  |  | 25.1 |
Amortization of/(Reserve for) Revenues Subject to Refund (1) | 7.0 |  |  | — |  |  | — |  |  | (0.1) |  |  | — |  |  | — |  |  | 6.9 |
Total Revenues from Contracts with Customers | 2,830.4 |  |  | 228.3 |  |  | 523.7 |  |  | 68.6 |  |  | 343.5 |  |  | (735.1) |  |  | 3,259.4 |
Alternative Revenue Programs | (37.7) |  |  | (2.8) |  |  | (55.1) |  |  | (3.6) |  |  | — |  |  | 52.6 |  |  | (46.6) |
Other Revenues | 2.4 |  |  | 0.1 |  |  | 0.2 |  |  | 0.1 |  |  | — |  |  | — |  |  | 2.8 |
Total Operating Revenues | $ | 2,795.1 |  |  | $ | 225.6 |  |  | $ | 468.8 |  |  | $ | 65.1 |  |  | $ | 343.5 |  |  | $ | (682.5) |  |  | $ | 3,215.6 |
| For the Nine Months Ended September 30, 2022
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 3,683.9 |  |  | $ | 870.0 |  |  | $ | — |  |  | $ | 109.1 |  |  | $ | — |  |  | $ | — |  |  | $ | 4,663.0 |
Commercial | 2,216.0 |  |  | 456.9 |  |  | — |  |  | 49.9 |  |  | — |  |  | (4.2) |  |  | 2,718.6 |
Industrial | 284.1 |  |  | 145.2 |  |  | — |  |  | 3.5 |  |  | — |  |  | (14.8) |  |  | 418.0 |
Total Retail Tariff Sales Revenues | 6,184.0 |  |  | 1,472.1 |  |  | — |  |  | 162.5 |  |  | — |  |  | (19.0) |  |  | 7,799.6 |
Wholesale Transmission Revenues | — |  |  | — |  |  | 1,301.0 |  |  | — |  |  | 79.4 |  |  | (1,047.3) |  |  | 333.1 |
Wholesale Market Sales Revenues | 895.2 |  |  | 89.3 |  |  | — |  |  | 2.8 |  |  | — |  |  | — |  |  | 987.3 |
Other Revenues from Contracts with Customers | 53.4 |  |  | 2.8 |  |  | 10.5 |  |  | 6.2 |  |  | 983.3 |  |  | (974.9) |  |  | 81.3 |
Amortization of/(Reserve for) Revenues Subject to Refund (1) | 71.9 |  |  | — |  |  | 0.7 |  |  | (0.9) |  |  | — |  |  | — |  |  | 71.7 |
Total Revenues from Contracts with Customers | 7,204.5 |  |  | 1,564.2 |  |  | 1,312.2 |  |  | 170.6 |  |  | 1,062.7 |  |  | (2,041.2) |  |  | 9,273.0 |
Alternative Revenue Programs | (26.2) |  |  | 4.3 |  |  | 48.9 |  |  | (2.8) |  |  | — |  |  | (46.9) |  |  | (22.7) |
Other Revenues | 7.5 |  |  | 0.9 |  |  | 0.5 |  |  | 0.4 |  |  | — |  |  | — |  |  | 9.3 |
Total Operating Revenues | $ | 7,185.8 |  |  | $ | 1,569.4 |  |  | $ | 1,361.6 |  |  | $ | 168.2 |  |  | $ | 1,062.7 |  |  | $ | (2,088.1) |  |  | $ | 9,259.6 |

37

| For the Three Months Ended September 30, 2023 |  | For the Three Months Ended September 30, 2022
(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH |  | CL&P |  | NSTAR Electric |  | PSNH
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 703.9 |  |  | $ | 480.5 |  |  | $ | 191.5 |  |  | $ | 739.1 |  |  | $ | 507.6 |  |  | $ | 246.2 |
Commercial | 286.4 |  |  | 389.4 |  |  | 88.7 |  |  | 311.2 |  |  | 469.6 |  |  | 110.4 |
Industrial | 39.0 |  |  | 31.9 |  |  | 23.6 |  |  | 41.9 |  |  | 39.3 |  |  | 24.4 |
Total Retail Tariff Sales Revenues | 1,029.3 |  |  | 901.8 |  |  | 303.8 |  |  | 1,092.2 |  |  | 1,016.5 |  |  | 381.0 |
Wholesale Transmission Revenues | 245.1 |  |  | 186.4 |  |  | 88.7 |  |  | 250.3 |  |  | 183.8 |  |  | 86.2 |
Wholesale Market Sales Revenues | 112.8 |  |  | 28.6 |  |  | 13.5 |  |  | 232.9 |  |  | 57.5 |  |  | 26.7 |
Other Revenues from Contracts with Customers | 7.7 |  |  | 12.4 |  |  | 5.0 |  |  | 7.5 |  |  | 10.7 |  |  | 3.1 |
Amortization of Revenues Subject to Refund (1) | 1.3 |  |  | — |  |  | — |  |  | 7.0 |  |  | — |  |  | — |
Total Revenues from Contracts with Customers | 1,396.2 |  |  | 1,129.2 |  |  | 411.0 |  |  | 1,589.9 |  |  | 1,268.5 |  |  | 497.0 |
Alternative Revenue Programs | (49.3) |  |  | (29.0) |  |  | 0.9 |  |  | (65.1) |  |  | (20.5) |  |  | (7.2) |
Other Revenues | 2.4 |  |  | 1.9 |  |  | 0.7 |  |  | 0.2 |  |  | 1.8 |  |  | 0.6 |
Eliminations | (159.2) |  |  | (148.6) |  |  | (59.5) |  |  | (155.9) |  |  | (144.3) |  |  | (59.8) |
Total Operating Revenues | $ | 1,190.1 |  |  | $ | 953.5 |  |  | $ | 353.1 |  |  | $ | 1,369.1 |  |  | $ | 1,105.5 |  |  | $ | 430.6 |
| For the Nine Months Ended September 30, 2023 |  | For the Nine Months Ended September 30, 2022
(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH |  | CL&P |  | NSTAR Electric |  | PSNH
Revenues from Contracts with Customers |  |  |  |  |  |  |  |  |  |  |
Retail Tariff Sales |  |  |  |  |  |  |  |  |  |  |
Residential | $ | 2,059.9 |  |  | $ | 1,318.7 |  |  | $ | 603.5 |  |  | $ | 1,864.4 |  |  | $ | 1,239.0 |  |  | $ | 580.5 |
Commercial | 836.7 |  |  | 1,121.0 |  |  | 287.5 |  |  | 808.7 |  |  | 1,128.8 |  |  | 280.5 |
Industrial | 104.1 |  |  | 95.7 |  |  | 68.7 |  |  | 111.4 |  |  | 104.0 |  |  | 68.7 |
Total Retail Tariff Sales Revenues | 3,000.7 |  |  | 2,535.4 |  |  | 959.7 |  |  | 2,784.5 |  |  | 2,471.8 |  |  | 929.7 |
Wholesale Transmission Revenues | 613.3 |  |  | 521.0 |  |  | 223.9 |  |  | 575.2 |  |  | 512.7 |  |  | 213.1 |
Wholesale Market Sales Revenues | 330.4 |  |  | 102.1 |  |  | 51.9 |  |  | 656.3 |  |  | 163.1 |  |  | 75.8 |
Other Revenues from Contracts with Customers | 24.7 |  |  | 36.0 |  |  | 12.2 |  |  | 22.8 |  |  | 34.1 |  |  | 8.8 |
Amortization of Revenues Subject to Refund (1) | 3.1 |  |  | — |  |  | — |  |  | 72.6 |  |  | — |  |  | — |
Total Revenues from Contracts with Customers | 3,972.2 |  |  | 3,194.5 |  |  | 1,247.7 |  |  | 4,111.4 |  |  | 3,181.7 |  |  | 1,227.4 |
Alternative Revenue Programs | 28.0 |  |  | (43.5) |  |  | 32.4 |  |  | 28.3 |  |  | (14.4) |  |  | 8.8 |
Other Revenues | 7.1 |  |  | 6.3 |  |  | 2.3 |  |  | 0.5 |  |  | 5.4 |  |  | 2.1 |
Eliminations | (444.1) |  |  | (428.5) |  |  | (159.1) |  |  | (449.6) |  |  | (420.4) |  |  | (161.2) |
Total Operating Revenues | $ | 3,563.2 |  |  | $ | 2,728.8 |  |  | $ | 1,123.3 |  |  | $ | 3,690.6 |  |  | $ | 2,752.3 |  |  | $ | 1,077.1 |

(1) Amortization of/(Reserve for) Revenues Subject to Refund within the Electric Distribution segment in the third quarter and the first nine months of 2022 primarily represents the reversal of a 2021 reserve at CL&P established to provide bill credits to customers as a result of the settlement agreement on October 1, 2021 and a storm performance penalty assessed by PURA. The reserve was reversed as customer credits were distributed to CL&P’s customers in retail electric rates. Total customer credits as a result of the 2021 settlement and civil penalty were $93.4 million. The settlement amount of $65 million was refunded over a two-month billing period from December 1, 2021 to January 31, 2022 and the civil penalty of $28.4 million was refunded over a one year billing period, which began September 1, 2021.
16. SEGMENT INFORMATION
Eversource is organized into the Electric Distribution, Electric Transmission, Natural Gas Distribution and Water Distribution reportable segments and Other based on a combination of factors, including the characteristics of each segments' services, the sources of operating revenues and expenses and the regulatory environment in which each segment operates. These reportable segments represent substantially all of Eversource's total consolidated revenues. Revenues from the sale of electricity, natural gas and water primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer. The Electric Distribution reportable segment includes the results of NSTAR Electric's solar power facilities. Eversource's reportable segments are determined based upon the level at which Eversource's chief operating decision maker assesses performance and makes decisions about the allocation of company resources.
The remainder of Eversource's operations is presented as Other in the tables below and primarily consists of 1) the equity in earnings of Eversource parent from its subsidiaries and intercompany interest income, both of which are eliminated in consolidation, and interest expense related to the debt of Eversource parent, 2) the revenues and expenses of Eversource Service, most of which are eliminated in consolidation, 3) the operations of CYAPC and YAEC, 4) the results of other unregulated subsidiaries, which are not part of its core business, and 5) Eversource parent's equity ownership interests that are not consolidated, which primarily include the offshore wind business, a natural gas pipeline owned by Enbridge, Inc., and a renewable energy investment fund that was liquidated in the first quarter of 2023.
38

In the ordinary course of business, Yankee Gas, NSTAR Gas and EGMA purchase natural gas transmission services from the Enbridge, Inc. natural gas pipeline project described above. These affiliate transaction costs total $77.7 million annually and are classified as Purchased Power, Purchased Natural Gas and Transmission on the Eversource statements of income.
Each of Eversource's subsidiaries, including CL&P, NSTAR Electric and PSNH, has one reportable segment.
Cash flows used for investments in plant included in the segment information below are cash capital expenditures that do not include amounts incurred on capital projects but not yet paid, cost of removal, AFUDC related to equity funds, and the capitalized and deferred portions of pension and PBOP income/expense. Eversource's segment information is as follows:

| For the Three Months Ended September 30, 2023
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Operating Revenues | $ | 2,371.3 |  |  | $ | 218.3 |  |  | $ | 491.6 |  |  | $ | 68.6 |  |  | $ | 394.7 |  |  | $ | (753.0) |  |  | $ | 2,791.5 |
Depreciation and Amortization | (0.7) |  |  | (38.0) |  |  | (94.5) |  |  | (13.9) |  |  | (40.7) |  |  | 2.3 |  |  | (185.5) |
Other Operating Expenses | (2,124.0) |  |  | (211.1) |  |  | (144.9) |  |  | (30.9) |  |  | (315.7) |  |  | 751.2 |  |  | (2,075.4) |
Operating Income/(Loss) | $ | 246.6 |  |  | $ | (30.8) |  |  | $ | 252.2 |  |  | $ | 23.8 |  |  | $ | 38.3 |  |  | $ | 0.5 |  |  | $ | 530.6 |
Interest Expense | $ | (76.8) |  |  | $ | (19.7) |  |  | $ | (43.0) |  |  | $ | (9.8) |  |  | $ | (111.4) |  |  | $ | 38.4 |  |  | $ | (222.3) |
Other Income, Net | 53.5 |  |  | 9.2 |  |  | 11.9 |  |  | 1.3 |  |  | 415.9 |  |  | (412.7) |  |  | 79.1 |
Net Income/(Loss) Attributable to Common Shareholders | 173.3 |  |  | (33.7) |  |  | 160.3 |  |  | 16.6 |  |  | 397.0 |  |  | (373.8) |  |  | 339.7 |
| For the Nine Months Ended September 30, 2023
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Operating Revenues | $ | 7,014.3 |  |  | $ | 1,672.6 |  |  | $ | 1,430.4 |  |  | $ | 177.0 |  |  | $ | 1,217.3 |  |  | $ | (2,295.1) |  |  | $ | 9,216.5 |
Depreciation and Amortization | 59.3 |  |  | (156.7) |  |  | (276.4) |  |  | (41.3) |  |  | (115.5) |  |  | 6.6 |  |  | (524.0) |
Other Operating Expenses | (6,371.4) |  |  | (1,280.8) |  |  | (409.4) |  |  | (87.5) |  |  | (992.6) |  |  | 2,290.0 |  |  | (6,851.7) |
Operating Income | $ | 702.2 |  |  | $ | 235.1 |  |  | $ | 744.6 |  |  | $ | 48.2 |  |  | $ | 109.2 |  |  | $ | 1.5 |  |  | $ | 1,840.8 |
Interest Expense | $ | (214.4) |  |  | $ | (62.4) |  |  | $ | (126.7) |  |  | $ | (28.4) |  |  | $ | (297.0) |  |  | $ | 104.8 |  |  | $ | (624.1) |
Impairment of Offshore Wind Investment | — |  |  | — |  |  | — |  |  | — |  |  | (401.0) |  |  | — |  |  | (401.0) |
Other Income, Net | 155.7 |  |  | 27.9 |  |  | 30.8 |  |  | 4.0 |  |  | 1,082.6 |  |  | (1,038.0) |  |  | 263.0 |
Net Income Attributable to Common Shareholders | 504.3 |  |  | 148.2 |  |  | 476.4 |  |  | 27.4 |  |  | 621.6 |  |  | (931.7) |  |  | 846.2 |
Cash Flows Used for Investments in Plant | 1,230.3 |  |  | 536.8 |  |  | 1,011.3 |  |  | 140.1 |  |  | 207.1 |  |  | — |  |  | 3,125.6 |

| For the Three Months Ended September 30, 2022
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Operating Revenues | $ | 2,795.1 |  |  | $ | 225.6 |  |  | $ | 468.8 |  |  | $ | 65.1 |  |  | $ | 343.5 |  |  | $ | (682.5) |  |  | $ | 3,215.6 |
Depreciation and Amortization | (256.9) |  |  | (25.1) |  |  | (85.1) |  |  | (12.7) |  |  | (35.4) |  |  | 1.8 |  |  | (413.4) |
Other Operating Expenses | (2,261.5) |  |  | (226.3) |  |  | (143.7) |  |  | (28.8) |  |  | (265.7) |  |  | 681.1 |  |  | (2,244.9) |
Operating Income/(Loss) | $ | 276.7 |  |  | $ | (25.8) |  |  | $ | 240.0 |  |  | $ | 23.6 |  |  | $ | 42.4 |  |  | $ | 0.4 |  |  | $ | 557.3 |
Interest Expense | $ | (64.5) |  |  | $ | (18.8) |  |  | $ | (36.6) |  |  | $ | (8.7) |  |  | $ | (69.6) |  |  | $ | 20.0 |  |  | $ | (178.2) |
Other Income, Net | 59.6 |  |  | 11.1 |  |  | 10.1 |  |  | 2.1 |  |  | 429.9 |  |  | (423.0) |  |  | 89.8 |
Net Income/(Loss) Attributable to Common Shareholders | 225.1 |  |  | (24.6) |  |  | 155.8 |  |  | 16.7 |  |  | 379.0 |  |  | (402.6) |  |  | 349.4 |
| For the Nine Months Ended September 30, 2022
Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
Operating Revenues | $ | 7,185.8 |  |  | $ | 1,569.4 |  |  | $ | 1,361.6 |  |  | $ | 168.2 |  |  | $ | 1,062.7 |  |  | $ | (2,088.1) |  |  | $ | 9,259.6 |
Depreciation and Amortization | (806.7) |  |  | (116.2) |  |  | (250.3) |  |  | (37.5) |  |  | (98.8) |  |  | 5.1 |  |  | (1,304.4) |
Other Operating Expenses | (5,743.2) |  |  | (1,244.3) |  |  | (414.3) |  |  | (82.9) |  |  | (876.5) |  |  | 2,081.9 |  |  | (6,279.3) |
Operating Income | $ | 635.9 |  |  | $ | 208.9 |  |  | $ | 697.0 |  |  | $ | 47.8 |  |  | $ | 87.4 |  |  | $ | (1.1) |  |  | $ | 1,675.9 |
Interest Expense | $ | (184.2) |  |  | $ | (51.2) |  |  | $ | (107.3) |  |  | $ | (25.2) |  |  | $ | (169.9) |  |  | $ | 46.3 |  |  | $ | (491.5) |
Other Income, Net | 160.1 |  |  | 31.9 |  |  | 28.3 |  |  | 6.4 |  |  | 1,280.1 |  |  | (1,251.5) |  |  | 255.3 |
Net Income Attributable to Common Shareholders | 495.0 |  |  | 147.2 |  |  | 455.8 |  |  | 29.4 |  |  | 1,163.6 |  |  | (1,206.3) |  |  | 1,084.7 |
Cash Flows Used for Investments in Plant | 823.9 |  |  | 424.5 |  |  | 823.3 |  |  | 103.4 |  |  | 177.6 |  |  | — |  |  | 2,352.7 |

The following table summarizes Eversource's segmented total assets:

Eversource (Millions of Dollars) | Electric Distribution |  | Natural Gas Distribution |  | Electric Transmission |  | Water Distribution |  | Other |  | Eliminations |  | Total
As of September 30, 2023 | $ | 28,840.9 |  |  | $ | 8,404.5 |  |  | $ | 14,693.4 |  |  | $ | 2,885.1 |  |  | $ | 29,019.0 |  |  | $ | (27,549.6) |  |  | $ | 56,293.3 |
As of December 31, 2022 | 27,365.0 |  |  | 8,084.9 |  |  | 13,369.5 |  |  | 2,783.8 |  |  | 26,365.2 |  |  | (24,737.5) |  |  | 53,230.9 |

39

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 Reports on Form 10-Q for the quarters ended March 31, 2023 and June 30, 2023, as well as the Eversource 2022 combined Annual Report on Form 10-K. References in this combined Quarterly Report on Form 10-Q to "Eversource," the "Company," "we," "us," and "our" refer to Eversource Energy and its consolidated subsidiaries. All per-share amounts are reported on a diluted basis. The unaudited condensed consolidated financial statements of Eversource, NSTAR Electric and PSNH and the unaudited condensed financial statements of CL&P are herein collectively referred to as the "financial statements."
Refer to the Glossary of Terms included in this combined Quarterly Report on Form 10-Q for abbreviations and acronyms used throughout this Management's Discussion and Analysis of Financial Condition and Results of Operations.
The only common equity securities that are publicly traded are common shares of Eversource. 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 investment, 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 investment, 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,
• 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,
• the ability to sell Eversource’s 50 percent interest in three offshore wind projects under development on the timeline we expect, to satisfy the investment tax credit qualifications related to the tax equity investment in the South Fork Wind project, the ability of the Revolution Wind and Sunrise Wind projects to qualify for the investment tax credit adders, and to successfully rebid the Sunrise Wind OREC contract at an increased value,
• 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 2022 combined Annual Report on Form 10-K. This combined Quarterly Report on Form 10-Q and Eversource's 2022 combined Annual Report on Form 10-K also describe material contingencies and critical accounting policies in the accompanying Management's Discussion and Analysis of Financial Condition and Results of Operations and Combined Notes to Financial Statements. We encourage you to review these items.
Financial Condition and Business Analysis
Executive Summary
Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business. Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), Yankee Gas, NSTAR Gas and EGMA (natural gas utilities) and Aquarion (water utilities). Eversource is organized into the electric distribution, electric transmission, natural gas distribution, and water distribution reportable segments.
The following items in this executive summary are explained in more detail in this combined Quarterly Report on Form 10-Q:
Earnings Overview and Future Outlook:
•We earned $339.7 million, or $0.97 per share, in the third quarter of 2023, and $846.2 million, or $2.42 per share, in the first nine months of 2023, compared with $349.4 million, or $1.00 per share, in the third quarter of 2022, and $1.08 billion, or $3.13 per share, in the first nine months of 2022. Results for the first nine months of 2023 include an after-tax impairment charge of $331.0 million or $0.95 per share, related to our offshore wind investment recorded at Eversource parent. Our results also include after-tax transaction, transition and other charges recorded at Eversource parent of $6.9 million in the first nine months of 2023, compared with $13.0 million in the first nine months of 2022 and $2.2 million in the third quarter of 2022. Excluding the offshore wind impairment and these other charges, our non-GAAP earnings were $1.18 billion, or $3.38 per share, in the first nine months of 2023, compared with $1.10 billion, or $3.17 per share, in the first nine months of 2022 and $351.6 million, or $1.01 per share, in the third quarter of 2022.
•We narrowed our projection to earn within a 2023 non-GAAP EPS guidance range of $4.30 per share to $4.43 per share, which excludes the impact of the expected sale of our offshore wind investment portfolio and associated impairment charge, the loss on disposition of land, and transaction costs. We also reaffirmed our projection of our long-term EPS growth rate through 2027 from our regulated utility businesses in the upper half of the 5 to 7 percent range.
Liquidity:
•Cash flows provided by operating activities totaled $1.17 billion in the first nine months of 2023, compared with $1.69 billion in the first nine months of 2022. Investments in property, plant and equipment totaled $3.13 billion in the first nine months of 2023, compared with $2.35 billion in the first nine months of 2022.
•Cash and Cash Equivalents totaled $78.8 million as of September 30, 2023, compared with $374.6 million as of December 31, 2022. Our available borrowing capacity under our commercial paper programs totaled $1.12 billion as of September 30, 2023.
•In the first nine months of 2023, we issued $4.34 billion of new long-term debt and we repaid $1.20 billion of long-term debt.
•On September 14, 2023, our Board of Trustees approved a common share dividend payment of $0.675 per share, paid on September 29, 2023 to shareholders of record as of September 25, 2023.
Strategic Developments:
•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 and Ørsted executed a Tax Equity Capital Contribution Agreement for South Fork Wind and funded this tax equity investment. Eversource made a contribution of $528 million using the proceeds from the lease area sale to provide tax equity for South Fork Wind through a new tax equity member interest. Eversource continues to progress towards completion of the sales process for the three contracted offshore wind projects.
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Earnings Overview
Consolidated: Below is a summary of our earnings by business, which also reconciles the non-GAAP financial measures of consolidated non-GAAP earnings and EPS, as well as EPS by business, to the most directly comparable GAAP measures of consolidated Net Income Attributable to Common Shareholders and diluted EPS.

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
| 2023 |  | 2022 |  | 2023 |  | 2022
(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) | $ | 339.7 |  |  | $ | 0.97 |  |  | $ | 349.4 |  |  | $ | 1.00 |  |  | $ | 846.2 |  |  | $ | 2.42 |  |  | $ | 1,084.7 |  |  | $ | 3.13 |
Regulated Companies | $ | 316.5 |  |  | $ | 0.91 |  |  | $ | 373.0 |  |  | $ | 1.07 |  |  | $ | 1,156.3 |  |  | $ | 3.30 |  |  | $ | 1,127.4 |  |  | $ | 3.26 |
Eversource Parent and Other Companies (Non-GAAP) | 23.2 |  |  | 0.06 |  |  | (21.4) |  |  | (0.06) |  |  | 27.8 |  |  | 0.08 |  |  | (29.7) |  |  | (0.09) |
Non-GAAP Earnings | $ | 339.7 |  |  | $ | 0.97 |  |  | $ | 351.6 |  |  | $ | 1.01 |  |  | $ | 1,184.1 |  |  | $ | 3.38 |  |  | $ | 1,097.7 |  |  | $ | 3.17 |
Impairment of Offshore Wind Investment (after-tax) (1) | — |  |  | — |  |  | — |  |  | — |  |  | (331.0) |  |  | (0.95) |  |  | — |  |  | — |
Loss on Land Disposition (after-tax) (2) | — |  |  | — |  |  | — |  |  | — |  |  | (4.8) |  |  | (0.01) |  |  | — |  |  | — |
Transaction and Transition Costs (after-tax) (3) | — |  |  | — |  |  | (2.2) |  |  | (0.01) |  |  | (2.1) |  |  | — |  |  | (13.0) |  |  | (0.04) |
Net Income Attributable to Common Shareholders (GAAP) | $ | 339.7 |  |  | $ | 0.97 |  |  | $ | 349.4 |  |  | $ | 1.00 |  |  | $ | 846.2 |  |  | $ | 2.42 |  |  | $ | 1,084.7 |  |  | $ | 3.13 |

(1) In the second quarter of 2023, Eversource recorded an impairment charge associated with its equity method investment in its offshore wind business resulting from the completion of the strategic review of its offshore wind investment portfolio.
(2) In the second quarter of 2023, Eversource recorded a loss on the disposition of land. The land was initially acquired to construct the Northern Pass Transmission project and was subsequently abandoned.
(3) The transaction costs are for the expected sale of our offshore wind investment portfolio and our water business acquisitions. The costs in 2022 also include costs associated with the transition of systems as a result of our purchase of the assets of Columbia Gas of Massachusetts (CMA) on October 9, 2020 and integrating the CMA assets onto Eversource’s systems.
Regulated Companies: Our regulated companies comprise the electric distribution, electric transmission, natural gas distribution, and water distribution segments. A summary of our segment earnings and EPS is as follows:

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
| 2023 |  | 2022 |  | 2023 |  | 2022
(Millions of Dollars, Except Per Share Amounts) | Amount |  | Per Share |  | Amount |  | Per Share |  | Amount |  | Per Share |  | Amount |  | Per Share
Electric Distribution | $ | 173.3 |  |  | $ | 0.50 |  |  | $ | 225.1 |  |  | $ | 0.65 |  |  | $ | 504.3 |  |  | $ | 1.44 |  |  | $ | 495.0 |  |  | $ | 1.43 |
Electric Transmission | 160.3 |  |  | 0.46 |  |  | 155.8 |  |  | 0.44 |  |  | 476.4 |  |  | 1.36 |  |  | 455.8 |  |  | 1.32 |
Natural Gas Distribution | (33.7) |  |  | (0.10) |  |  | (24.6) |  |  | (0.07) |  |  | 148.2 |  |  | 0.42 |  |  | 147.2 |  |  | 0.42 |
Water Distribution | 16.6 |  |  | 0.05 |  |  | 16.7 |  |  | 0.05 |  |  | 27.4 |  |  | 0.08 |  |  | 29.4 |  |  | 0.09 |
Net Income - Regulated Companies | $ | 316.5 |  |  | $ | 0.91 |  |  | $ | 373.0 |  |  | $ | 1.07 |  |  | $ | 1,156.3 |  |  | $ | 3.30 |  |  | $ | 1,127.4 |  |  | $ | 3.26 |

Our electric distribution segment earnings decreased $51.8 million in the third quarter of 2023, as compared to the third quarter of 2022, due primarily to lower revenues at NSTAR Electric as a result of a rate design change approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues, higher operations and maintenance expense due primarily to higher storm-related costs, a higher effective tax rate, higher interest expense, higher depreciation expense, and higher property and other tax expense. Those earnings decreases were partially offset by higher earnings from CL&P's capital tracking mechanism due to increased electric system improvements, a base distribution rate increase effective January 1, 2023 at NSTAR Electric, and an increase in interest income primarily on regulatory deferrals.
As part of the 2022 NSTAR Electric rate case decision, certain customer rates changed from seasonal demand charges to a single annual demand charge effective January 1, 2023, resulting in a shift in the timing of revenues and earnings recognized quarterly in 2023, as compared to 2022, but with no impact on an annual basis. This rate design change will result in higher revenues in each of the first and fourth quarters of 2023 of approximately $21 million, offset by lower revenues in the third quarter of 2023 of approximately $42 million, as compared to the same periods in 2022.
Our electric distribution segment earnings increased $9.3 million in the first nine months of 2023, as compared to the first nine months of 2022, due primarily to a base distribution rate increase effective January 1, 2023 at NSTAR Electric, higher earnings from CL&P's capital tracking mechanism due to increased electric system improvements, the impact of a new regulatory tracking mechanism at PSNH that allows for the recovery of previously incurred operating expenses associated with poles acquired on May 1, 2023, an increase in interest income primarily on regulatory deferrals, and higher AFUDC equity income. Those earnings increases were partially offset by higher interest expense, higher operations and maintenance expense, lower revenues at NSTAR Electric as a result of a rate design change approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues, higher property and other tax expense, higher depreciation expense, and a higher effective tax rate.
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Our electric transmission segment earnings increased $4.5 million and $20.6 million in the third quarter and the first nine months of 2023, respectively, as compared to the third quarter and the first nine months of 2022, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure.
Our natural gas distribution segment loss increased $9.1 million in the third quarter of 2023, as compared to the third quarter of 2022, due primarily to an unfavorable regulatory adjustment resulting from NSTAR Gas’ GSEP reconciliation filing, higher depreciation expense, higher operations and maintenance expense, and a higher effective tax rate, partially offset by higher earnings from capital tracking mechanisms due to continued investments in natural gas infrastructure and lower property tax expense.
Our natural gas distribution segment earnings increased $1.0 million in the first nine months of 2023, as compared to the first nine months of 2022, due primarily to higher earnings from capital tracking mechanisms due to continued investments in natural gas infrastructure, base distribution rate increases effective November 1, 2022 at NSTAR Gas and EGMA, an increase in interest income primarily on regulatory deferrals, and lower operations and maintenance expense. Those earnings increases were partially offset by higher depreciation expense, an unfavorable regulatory adjustment resulting from NSTAR Gas’ GSEP reconciliation filing, a higher effective tax rate, higher interest expense, and higher property tax expense.
Our water distribution segment earnings decreased $0.1 million and $2.0 million in the third quarter and the first nine months of 2023, respectively, as compared to the third quarter and the first nine months of 2022. Lower first nine months earnings were due primarily to higher operations and maintenance expense and higher interest expense.
Eversource Parent and Other Companies: Eversource parent and other companies’ earnings increased $46.8 million in the third quarter of 2023, as compared to the third quarter of 2022, due primarily to a lower effective tax rate as a result of the ability to utilize tax credits and benefits, partially offset by higher interest expense.
Eversource parent and other companies’ losses increased $267.4 million in the first nine months of 2023, as compared to the first nine months of 2022, due primarily to the impairment of Eversource Parent’s offshore wind investment in the second quarter of 2023, which resulted in an after-tax charge of $331.0 million, or $0.95 per share. Earnings were also unfavorably impacted by higher interest expense and 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. Earnings benefited by a lower effective tax rate as a result of the ability to utilize tax credits and benefits in the third quarter of 2023, as well as a decrease in after-tax transaction and transition costs of $10.9 million in the first nine months of 2023, as compared to the first nine months of 2022. Additionally, earnings were favorably impacted by a benefit in both the first and second quarters of 2023 from the liquidation of Eversource Parent’s equity method investment in a renewable energy fund, partially offset by a charitable contribution made with a portion of the proceeds from the liquidation in the first quarter of 2023.
Liquidity
Sources and Uses of Cash: Eversource’s regulated business is capital intensive and requires considerable capital resources. Eversource’s regulated companies’ capital resources are provided by cash flows generated from operations, short-term borrowings, long-term debt issuances, capital contributions from Eversource parent, and existing cash, and are used to fund their liquidity and capital requirements. Eversource’s regulated companies typically maintain minimal cash balances and use short-term borrowings to meet their working capital needs and other cash requirements. Short-term borrowings are also used as a bridge to long-term debt financings. The levels of short-term borrowing may vary significantly over the course of the year due to the impact of fluctuations in cash flows from operations (including timing of storm costs and regulatory recoveries), dividends paid, capital contributions received and the timing of long-term debt financings.
Eversource, CL&P, NSTAR Electric and PSNH each uses its available capital resources to fund its respective construction expenditures, meet debt requirements, pay operating costs, including storm-related costs, pay dividends, and fund other corporate obligations, such as pension contributions. Eversource's regulated companies recover their electric, natural gas and water distribution construction expenditures as the related project costs are depreciated over the life of the assets. This impacts the timing of the revenue stream designed to fully recover the total investment plus a return on the equity and debt used to finance the investments. Eversource's regulated companies spend a significant amount of cash on capital improvements and construction projects that have a long-term return on investment and recovery period. In addition, Eversource uses its capital resources to fund investments in its offshore wind business, which are recognized as long-term assets.
We expect the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with our existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities.
Cash and Cash Equivalents totaled $78.8 million as of September 30, 2023, compared with $374.6 million as of December 31, 2022.
Short-Term Debt - Commercial Paper Programs and Credit Agreements: Eversource parent has a $2.00 billion commercial paper program allowing Eversource parent to issue commercial paper as a form of short-term debt. Eversource parent, CL&P, PSNH, NSTAR Gas, Yankee Gas, EGMA and Aquarion Water Company of Connecticut are parties to a five-year $2.00 billion revolving credit facility, which terminates on October 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, and serves to backstop NSTAR Electric's $650 million commercial paper program.
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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
| September 30, 2023 |  | December 31, 2022 |  | September 30, 2023 |  | December 31, 2022 |  | September 30, 2023 |  | December 31, 2022
(Millions of Dollars) |  |  |  |  |
Eversource Parent Commercial Paper Program | $ | 1,320.3 |  |  | $ | 1,442.2 |  |  | $ | 679.7 |  |  | $ | 557.8 |  |  | 5.53 | % |  | 4.63 | %
NSTAR Electric Commercial Paper Program | 209.5 |  |  | — |  |  | 440.5 |  |  | 650.0 |  |  | 5.35 | % |  | — | %

There were no borrowings outstanding on the revolving credit facilities as of September 30, 2023 or December 31, 2022.
CL&P and PSNH have uncommitted line of credit agreements totaling $375 million and $250 million, respectively, which will expire in 2024. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of September 30, 2023.
Amounts outstanding under the commercial paper programs are included in Notes Payable and classified in current liabilities on the Eversource and NSTAR Electric balance sheets, as all borrowings are outstanding for no more than 364 days at one time.
Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of September 30, 2023, there were intercompany loans from Eversource parent to CL&P of $213.4 million and to PSNH of $0.1 million. As of December 31, 2022, there were intercompany loans from Eversource parent to PSNH of $173.3 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time.
Availability under Long-Term Debt Issuance Authorizations: On June 7, 2023, PURA approved Yankee Gas’ request for authorization to issue up to $350 million in long-term debt through December 31, 2024.
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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 2023 Series A First Mortgage Bonds | 5.25 | % |  | $ | 500.0 |  |  | January 2023 |  | January 2053 |  | Repaid 2013 Series A Bonds at maturity and short-term debt, and paid capital expenditures and working capital
CL&P 2013 Series A First Mortgage Bonds | 2.50 | % |  | (400.0) |  |  | January 2023 |  | January 2023 |  | Paid at maturity
CL&P 2023 Series B First Mortgage Bonds | 4.90 | % |  | 300.0 |  |  | July 2023 |  | July 2033 |  | Repaid short-term debt, paid capital expenditures and working capital
NSTAR Electric 2023 Debentures | 5.60 | % |  | 150.0 |  |  | September 2023 |  | October 2028 |  | Repay Series G Senior Notes at maturity and short-term debt and for general corporate purposes
PSNH Series W First Mortgage Bonds | 5.15 | % |  | 300.0 |  |  | January 2023 |  | January 2053 |  | Repaid short-term debt, paid capital expenditures and working capital
PSNH Series X First Mortgage Bonds | 5.35 | % |  | 300.0 |  |  | September 2023 |  | October 2033 |  | Repaid Series S Bonds at maturity and for general corporate purposes
PSNH Series S First Mortgage Bonds | 3.50 | % |  | (325.0) |  |  | November 2023 |  | November 2023 |  | Paid at maturity
Eversource Parent Series Z Senior Notes | 5.45 | % |  | 750.0 |  |  | March 2023 |  | March 2028 |  | Repaid Series F Senior Notes at maturity and short-term debt
Eversource Parent Series F Senior Notes | 2.80 | % |  | (450.0) |  |  | May 2023 |  | May 2023 |  | Paid at maturity
Eversource Parent Series Z Senior Notes | 5.45 | % |  | 550.0 |  |  | May 2023 |  | March 2028 |  | Repay Series T Senior Notes and Series N Senior Notes at maturity and short-term debt
Eversource Parent Series AA Senior Notes | 4.75 | % |  | 450.0 |  |  | May 2023 |  | May 2026 |  | Repay Series T Senior Notes and Series N Senior Notes at maturity and short-term debt
Eversource Parent Series BB Senior Notes | 5.125 | % |  | 800.0 |  |  | May 2023 |  | May 2033 |  | Repay Series T Senior Notes and Series N Senior Notes at maturity and short-term debt
Eversource Parent Variable Rate Series T Senior Notes | SOFR plus 0.25% |  | (350.0) |  |  | August 2023 |  | August 2023 |  | Paid at maturity
Yankee Gas Series V First Mortgage Bonds | 5.51 | % |  | 170.0 |  |  | August 2023 |  | August 2030 |  | Repaid short-term debt and general corporate purposes
Aquarion Water Company of Connecticut Senior Notes | 5.89 | % |  | 50.0 |  |  | September 2023 |  | October 2043 |  | Repaid existing indebtedness, paid capital expenditures and general corporate purposes

Rate Reduction Bonds: PSNH's RRB payments consist of principal and interest and are paid semi-annually. PSNH paid $43.2 million of RRB principal payments and $16.2 million of interest payments in the first nine months of 2023, and paid $43.2 million of RRB principal payments and $17.6 million of interest payments in the first nine months of 2022.
Cash Flows: Cash flows from operating activities primarily result from the transmission and distribution of electricity, and the distribution of natural gas and water. Cash flows provided by operating activities totaled $1.17 billion in the first nine months of 2023, compared with $1.69 billion in the first nine months of 2022. Operating cash flows were unfavorably impacted by an increase in regulatory under-recoveries driven primarily by the timing of collections for the CL&P non-bypassable FMCC and other regulatory tracking mechanisms, the timing of cash payments made on our accounts payable and the timing of other working capital items. In 2023, CL&P increased the flow back to customers of net revenues generated by long-term state-approved energy contracts by providing these credits to customers through the non-bypassable FMCC retail rate. The reduction in the CL&P non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $717.3 million in the first nine months of 2023, as compared to the first nine months of 2022, and is presented as a cash outflow in Amortization on the statement of cash flows. The impact of regulatory collections are included in both Regulatory Recoveries and Amortization on the statements of cash flows. These unfavorable impacts were partially offset by the timing of cash collections on our accounts receivable, the absence in 2023 of $78.4 million of payments in 2022 related to withheld property taxes at our Massachusetts companies, a decrease of $75.0 million in pension contributions made in 2023 compared to 2022, the absence in 2023 of $72.0 million of customer credits distributed in 2022 at CL&P as a result of the October 2021 settlement agreement and the 2021 storm performance penalty for CL&P’s response to Tropical Storm Isaias, a $54.2 million increase in operating cash flows due to income tax refunds received in 2023 compared to income tax payments in 2022, a decrease in cost of removal expenditures and a $12.7 million decrease in cash payments for storm costs.
On September 14, 2023, our Board of Trustees approved a common share dividend payment of $0.675 per share, paid on September 29, 2023 to shareholders of record as of September 25, 2023. In the first nine months of 2023, we paid cash dividends of $688.9 million and issued non-cash dividends of $17.6 million in the form of treasury shares, totaling dividends of $706.5 million. In the first nine months of 2022, we paid cash dividends of $643.6 million and issued non-cash dividends of $17.4 million in the form of treasury shares, totaling dividends of $661.0 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.
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In the first nine months of 2023, CL&P, NSTAR Electric and PSNH paid $247.8 million, $327.4 million, and $112.0 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 nine months of 2023, investments for Eversource, CL&P, NSTAR Electric, and PSNH were $3.13 billion, $797.3 million, $1.01 billion, and $431.9 million, respectively. Capital expenditures were primarily for continuing projects to maintain and improve infrastructure and operations, including enhancing reliability to the transmission and distribution systems.
Investments in Unconsolidated Affiliates within investing activities on the statements of cash flows includes proceeds received from the liquidation of an equity method investment in a renewable energy investment fund of $147.0 million and proceeds received from the sale of an uncommitted lease area in our offshore wind business of $625 million in the first nine months of 2023.
On October 16, 2023, Eversource received a $318 million distribution from its offshore wind investment, primarily as a result of being a 50 percent joint owner in South Fork Wind, which was restructured as a tax equity investment. This distribution was used to pay down short-term debt.
Contractual Obligations: Our cash requirements from contractual obligations were reported in Item 7, "Management’s Discussion and Analysis of Financial Condition and Results of Operations," of the Eversource 2022 Form 10-K. There have been no material changes to our cash requirements from contractual obligations and payment schedules previously disclosed in our 2022 Form 10-K.
Credit Ratings: On September 14, 2023, S&P changed Eversource parent’s and NSTAR Electric’s outlook from positive to stable and CL&P’s outlook from stable to negative. On October 26, 2023, S&P changed Eversource parent’s, NSTAR Electric’s, and PSNH’s outlook from stable to negative. On October 27, 2023, Fitch changed Eversource parent’s and NSTAR Electric’s outlook from stable to negative. On October 27, 2023, Moody’s downgraded the ratings on Eversource parent and NSTAR Electric and revised the outlooks from negative to stable.
A summary of our corporate credit ratings and outlooks by S&P, Moody's, and Fitch is as follows:

| S&P |  | Moody's |  | Fitch
| Current |  | Outlook |  | Current |  | Outlook |  | Current |  | Outlook
Eversource Parent | A- |  | Negative |  | Baa2 |  | Stable |  | BBB+ |  | Negative
CL&P | A |  | Negative |  | A3 |  | Stable |  | A- |  | Stable
NSTAR Electric | A |  | Negative |  | A2 |  | Stable |  | A |  | Negative
PSNH | A |  | Negative |  | A3 |  | Stable |  | A- |  | Stable

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

S&P | S&P |  | Moody’s | Fitch
Eversource Parent | BBB+ |  | Baa2 | BBB+
CL&P | A+ |  | A1 | A+
NSTAR Electric | A |  | A2 | A+
PSNH | A+ |  | A1 | A+

Impact of COVID-19
The financial impacts of COVID-19 as it relates to our businesses primarily relate to collectability of customer receivables and the outcome of future proceedings before our state regulatory commissions to recover our incremental uncollectible customer receivable costs associated with COVID-19. As of both September 30, 2023 and December 31, 2022, the total amount incurred as a result of COVID-19 included in the allowance for uncollectible accounts was $50.9 million at Eversource, $16.0 million at CL&P, and $4.1 million at NSTAR Electric. At our Connecticut and Massachusetts utilities, the COVID-19 related uncollectible amounts were deferred either as incremental regulatory costs or deferred through existing regulatory tracking mechanisms that recover uncollectible energy supply costs, as management believes it is probable that these costs will ultimately be recovered from customers in future rates.
Business Development and Capital Expenditures
Our consolidated capital expenditures, including amounts incurred but not paid, cost of removal, AFUDC, and the capitalized and deferred portions of pension and PBOP income/expense (all of which are non-cash factors), totaled $3.21 billion in the first nine months of 2023, compared to $2.52 billion in the first nine months of 2022. These amounts included $172.3 million and $177.3 million in the first nine months of 2023 and 2022, respectively, related to information technology and facilities upgrades and enhancements, primarily at Eversource Service and The Rocky River Realty Company.
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Electric Transmission Business: Our consolidated electric transmission business capital expenditures increased by $154.8 million in the first nine months of 2023, as compared to the first nine months of 2022. A summary of electric transmission capital expenditures by company is as follows:

| For the Nine Months Ended September 30,
(Millions of Dollars) | 2023 |  | 2022
CL&P | $ | 282.1 |  |  | $ | 284.4 |
NSTAR Electric | 388.3 |  |  | 283.0 |
PSNH | 283.1 |  |  | 231.3 |
Total Electric Transmission | $ | 953.5 |  |  | $ | 798.7 |

Our transmission projects are designed to improve the reliability of the electric grid, meet customer demand for power and increases in electrification of municipal infrastructure, strengthen the electric grid's resilience against extreme weather and other safety and security threats, and enable integration of increasing amounts of clean power generation from renewable sources, such as solar, battery storage, and offshore wind. In Connecticut, Massachusetts and New Hampshire, our transmission projects include transmission line upgrades, the installation of new transmission interconnection facilities, substations and lines, and transmission substation enhancements.
Our transmission projects in Massachusetts include electric transmission upgrades in the greater Boston metropolitan area. Two of these upgrades, the Mystic-Woburn and the Wakefield-Woburn reliability projects, are under construction and are expected to be placed in service by the fourth quarter of 2023. Construction on the last remaining upgrade, the Sudbury-Hudson Reliability Project, commenced in the fourth quarter of 2022. We spent $83 million during the first nine months of 2023 and we expect to make additional capital expenditures of approximately $170 million on these remaining transmission upgrades.
Distribution Business: A summary of distribution capital expenditures is as follows:

| For the Nine Months Ended September 30,
(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH |  | Total Electric |  | Natural Gas |  | Water |  | Total
2023 |  |  |  |  |  |  |  |  |  |  |  |  |
Basic Business | $ | 209.4 |  |  | $ | 271.3 |  |  | $ | 60.5 |  |  | $ | 541.2 |  |  | $ | 145.9 |  |  | $ | 11.8 |  |  | $ | 698.9 |
Aging Infrastructure | 194.2 |  |  | 216.6 |  |  | 72.3 |  |  | 483.1 |  |  | 507.8 |  |  | 99.4 |  |  | 1,090.3 |
Load Growth and Other | 88.0 |  |  | 136.3 |  |  | 22.9 |  |  | 247.2 |  |  | 46.3 |  |  | 0.5 |  |  | 294.0 |
Total Distribution | $ | 491.6 |  |  | $ | 624.2 |  |  | $ | 155.7 |  |  | $ | 1,271.5 |  |  | $ | 700.0 |  |  | $ | 111.7 |  |  | $ | 2,083.2 |
2022 |  |  |  |  |  |  |  |  |  |  |  |  |
Basic Business | $ | 186.6 |  |  | $ | 118.3 |  |  | $ | 40.2 |  |  | $ | 345.1 |  |  | $ | 135.6 |  |  | $ | 9.5 |  |  | $ | 490.2 |
Aging Infrastructure | 150.7 |  |  | 159.7 |  |  | 47.1 |  |  | 357.5 |  |  | 378.8 |  |  | 87.4 |  |  | 823.7 |
Load Growth and Other | 39.9 |  |  | 122.0 |  |  | 20.5 |  |  | 182.4 |  |  | 43.2 |  |  | 0.7 |  |  | 226.3 |
Total Distribution | $ | 377.2 |  |  | $ | 400.0 |  |  | $ | 107.8 |  |  | $ | 885.0 |  |  | $ | 557.6 |  |  | $ | 97.6 |  |  | $ | 1,540.2 |

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: Our offshore wind business includes 50 percent ownership interests in wind partnerships, which collectively hold PPAs for the Revolution Wind and South Fork Wind projects, an OREC contract for the Sunrise Wind project, and a tax equity investment in South Fork Wind. Our offshore wind projects are being developed and constructed through joint and equal partnerships with Ørsted.
As of September 30, 2023 and December 31, 2022, Eversource's total equity investment balance in its offshore wind business was $2.58 billion and $1.95 billion, respectively.
Expected Sale of Offshore Wind Investment: On May 25, 2023, Eversource announced that it had completed the strategic review of its offshore wind investment portfolio and determined that it would continue to pursue the sale of its offshore wind investment. The sale process of Eversource’s existing 50 percent interest in its three jointly-owned, contracted offshore wind projects continues to progress, and Eversource anticipates an announcement in the near term.
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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. Eversource and Ørsted had entered into the purchase and sale agreement of this uncommitted lease area on May 25, 2023.
In September of 2023, Eversource and Ørsted executed a Tax Equity Capital Contribution Agreement for South Fork Wind and funded this tax equity investment. Eversource made a contribution of $528 million using the proceeds from the lease area sale to provide tax equity for South Fork Wind through this new tax equity member interest. In exchange for its investment, Eversource expects to receive investment tax credits as turbines are placed in service for South Fork Wind. These credits will be utilized to reduce Eversource’s federal tax liability, including refunds expected over the next twelve to eighteen months. South Fork Wind is expected to be fully in-service in early 2024.
In the second quarter of 2023, in connection with the conclusion of the strategic review, Eversource evaluated its aggregate investment in the projects, uncommitted lease area, and other related capitalized costs and determined that the carrying value of the equity method offshore wind investment exceeded the fair value of the investment and that the decline was other-than-temporary. The estimate of fair value was based on future cash flows arising from the expected sale price of Eversource’s 50 percent interest in the three contracted projects based on the most recent bid value, the sale price of the uncommitted lease area included in the purchase and sale agreement, expected investment tax credits and potential investment tax credit adder amounts, and the value of the tax equity ownership interest. As a result, Eversource recognized a pre-tax other-than-temporary impairment charge of $401.0 million ($331.0 million after-tax, which includes the impact of a $40 million valuation allowance for federal and state capital loss carryforwards) in the second quarter of 2023.
The impairment evaluation involved judgments in developing the estimate and timing of future cash flows arising from the anticipated sale transactions, including future project spending amounts that could reduce the ultimate sales value, expected ability to qualify the Revolution Wind and Sunrise Wind projects for investment tax credit adders, the expectation of improved Sunrise Wind OREC contract value, and the selection of the discount rate used to determine fair value. The assumptions used in the discounted cash flow analysis are subject to inherent uncertainties and subjectivity. The use of different assumptions, estimates, or judgments with respect to the estimation of future cash flows could materially increase the impairment charge. The impairment evaluation was based on best information available at the impairment assessment date. Management evaluated its investment as of September 30, 2023 and concluded that, considering all facts and circumstances as of that date, there were no impairment triggering events in the third quarter of 2023. Accordingly, no additional impairment charge was applicable.
The impairment valuation model includes a key judgment of future cash flows from the sale of the Sunrise Wind project of up to $450 million, which was based on the expectation of a successful repricing of the Sunrise Wind OREC contract. In June 2023, Sunrise Wind had filed a petition with the New York State Public Service Commission for an order authorizing NYSERDA to amend the Sunrise Wind OREC contract to incorporate interconnection costs and to provide for inflation adjustments. This value for Sunrise Wind was assessed through September 30, 2023, assuming that the contract repricing would be successful given NYSERDA’s public support for pricing adjustments. On October 12, 2023, the New York State Public Service Commission denied this petition. New York is in the process of establishing an expedited offshore wind renewable energy solicitation, with NYSERDA issuing a request for information to potential bidders on October 26, 2023. Eversource and Ørsted are evaluating the next steps in this re-bidding process. Given the unfavorable development on the OREC pricing denial in the fourth quarter of 2023, Eversource will evaluate the project’s next steps and probability of success in the New York re-bidding process. It is possible that adverse developments could impact the fair value of Sunrise Wind and could result in a significant impairment in a future period.
Another key assumption in the impairment model of our offshore wind investment was investment tax credit (“ITC”) adders that were included in the Inflation Reduction Act. An ITC adder is an additional 10 percent of credit value for ITC eligible costs and include two distinct qualifications related to either using domestic sourced materials (domestic content) or construction of an onshore substation in a designated community (energy communities). Similar to the base ITC of 30 percent of the eligible costs, any ITC adders generated would be used to reduce Eversource’s current federal tax liability and could be used to receive tax refunds from prior years as well. Management estimated in the second quarter of 2023 that it would be able to realize a 10 percent ITC adder for both the Sunrise Wind and Revolution Wind projects, which is a total expected value of approximately $400 million. There is uncertainty at this time as to whether or not those ITC adders can be achieved, and management continues to evaluate the project’s qualifications and to monitor guidance issued by the United States Treasury Department. A change in the expected value or qualification of ITC adders could result in a significant impairment in a future period.
The three contracted offshore wind projects also are facing construction and scheduling related pressures, which may cause additional required capital contributions from Eversource that are not factored into the expected sales price. It is possible that these future spending amounts could result in a significant impairment charge in a future period.
Management will continue to monitor and evaluate all facts and circumstances in the offshore wind sales process and the impact on its investment balance. The fair value of the investment will be updated based on changes in critical assumptions, the final sales price, and final sales terms. It is possible that there will be changes in our expectations of the timing of the sale of our three projects. Adverse changes in facts and circumstances of estimates and timing of future cash flows and the factors described above could result in the recognition of additional, significant impairment charges and could be material to the financial statements.
The impairment charge was a non-cash charge and did not impact Eversource’s cash position. Eversource will continue to make future cash expenditures for required cash contributions to its offshore wind investment up to the time of the sale of the offshore wind projects. Proceeds from the transaction will be used to pay off parent company debt.
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Proceeds received from the sale of the uncommitted lease area and the contribution for the tax equity investment in South Fork Wind, along with continued capital contributions in the offshore wind investment, are included in Investments in Unconsolidated Affiliates within investing activities on the statement of cash flows for the nine months ended September 30, 2023.
Contracts, Permitting and Construction of Offshore Wind Projects: The following table provides a summary of the Eversource and Ørsted major projects with announced contracts:

Wind Project | State Servicing | Size (MW) | Term (Years) | Price per MWh | Pricing Terms | Contract Status
Revolution Wind | Rhode Island | 400 | 20 | $98.43 | Fixed price contract; no price escalation | Approved
Revolution Wind | Connecticut | 304 | 20 | $98.43 - $99.50 | Fixed price contracts; no price escalation | Approved
South Fork Wind | New York (LIPA) | 90 | 20 | $160.33 | 2 percent average price escalation | Approved
South Fork Wind | New York (LIPA) | 40 | 20 | $86.25 | 2 percent average price escalation | Approved
Sunrise Wind | New York (NYSERDA) | 924 | 25 | $110.37 (1) | Fixed price contract; no price escalation | Approved

(1) Index OREC strike price.
Revolution Wind and Sunrise Wind projects are subject to receipt of federal, state and local approvals necessary to construct and operate the projects. The federal permitting process is led by BOEM, and state approvals are required from New York, Rhode Island and Massachusetts. Significant delays in the siting and permitting process resulting from the timeline for obtaining approval from BOEM and the state and local agencies could adversely impact the timing of these projects' in-service dates.
Federal Siting and Permitting Process: The federal siting and permitting process for each of our offshore wind projects commence with the filing of a Construction and Operations Plan (COP) application with BOEM. BOEM provides a review schedule for the project’s COP approval and conducts environmental and technical reviews of the COP. BOEM issues an Environmental Impact Statement (EIS) that assesses the environmental, social, and economic impacts of constructing the project and recommends measures to minimize impacts. The Final EIS will inform BOEM in deciding whether to approve the project or to approve with modifications and BOEM will then issue its Record of Decision. BOEM issues its final approval of the COP following the Record of Decision.
Revolution Wind and Sunrise Wind filed their COP applications with BOEM in March 2020 and September 2020, respectively. BOEM released its Draft EIS on September 2, 2022 and its Final EIS on July 17, 2023 for the Revolution Wind project, and released its Draft EIS on December 16, 2022 for the Sunrise Wind project. For Revolution Wind, on August 21, 2023, BOEM issued its Record of Decision, which concluded BOEM’s environmental review of the project and identified the recommended configuration. Final approval is expected in the fourth quarter of 2023. For Sunrise Wind, a Final EIS and Record of Decision are expected in the fourth quarter of 2023, and final approval is expected in the first quarter of 2024.
South Fork Wind, Revolution Wind and Sunrise Wind are each designated as a “Covered Project” pursuant to Title 41 of the Fixing America’s Surface Transportation Act (FAST41) and a Major Infrastructure Project under Section 3(e) of Executive Order 13807, which provides greater federal attention on meeting the projects’ permitting timelines.
State and Local Siting and Permitting Process: State permitting applications in Rhode Island for Revolution Wind and in New York for Sunrise Wind were filed in December 2020. On July 8, 2022, the Rhode Island Energy Facilities Siting Board issued a Final Decision and Order approving the Revolution Wind project and granting a license to construct and operate.
On November 17, 2022, the New York Public Service Commission approved an order adopting a Joint Proposal filed by Sunrise Wind and granting a Certificate of Environmental Compatibility and Public Need. On November 18, 2022, Sunrise Wind filed its Phase 1 Environmental Management and Construction Plan (EM&CP) with the New York Public Service Commission, which details the plans on limited onshore construction activities subject to state and local jurisdiction. On March 27, 2023, Sunrise Wind filed its EM&CP for Phase 2, which covers the remainder of the project components. On June 22, 2023, Sunrise Wind received approval of the Phase 1 EM&CP. On July 13, 2023, the New York State Public Service Commission approved Sunrise Wind’s notice for authorization to proceed with construction for Phase 1.
On November 9, 2022, the Towns of Brookhaven and Suffolk County executed the easements and other real estate rights necessary to construct the Sunrise Wind project. On November 28, 2022, the Town of North Kingstown and the Quonset Development Corporation approved Revolution Wind’s real estate PILOT terms and the personal property PILOT agreement necessary to construct the Revolution Wind project.
Construction Process: South Fork Wind received all required approvals to start construction and the project entered the construction phase in early 2022. All major onshore construction activities, including the project’s underground onshore transmission line and the onshore interconnection facility located in East Hampton, New York are complete. Offshore construction activities began in the fourth quarter of 2022 and continue, with installation of the subsea transmission cable, the monopile foundations and offshore substation complete. The remainder of the marine construction activities, primarily installation of the project’s 11-megawatt wind turbines, are expected to continue throughout the rest of 2023 and into early 2024. South Fork Wind faces several challenges and appeals of New York State and federal agency approvals, however it believes it is probable it will be able to overcome these challenges.
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For Revolution Wind, on October 31, 2023, the joint venture made its final investment decision to advance to full onshore and offshore construction and installation, and major construction is expected to begin in the fourth quarter of 2023 once all necessary federal, state and local approvals are received. For Sunrise Wind, once all necessary federal, state and local approvals are received and the joint venture has made its final investment decision, then major construction is expected to begin. Both projects have started limited onshore construction activities.
Projected In-Service Dates: We expect the South Fork Wind project to be fully in-service in early 2024. For Revolution Wind and Sunrise Wind, based on the updated BOEM permit schedules outlining when BOEM will complete its review of the COP, we currently expect in-service dates in late 2025 for both projects.
Projected Investments: We currently expect to make investments in our offshore wind business between $1.4 billion and $1.6 billion in 2023 and expect to make investments for our three projects in total between $2.1 billion and $2.4 billion from 2024 through 2026. These estimates assume that the three projects are completed and are in-service by the end of 2025, as planned. These projected investments are expected to be impacted by the expected future sale of our offshore wind investment and related developments.
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 September 30, 2023 and December 31, 2022. This reserve represents the difference between the billed rates during the second complaint period and a 10.57 percent base ROE and 11.74 percent incentive cap. The reserve consisted of $21.4 million for CL&P, $14.6 million for NSTAR Electric and $3.1 million for PSNH as of both September 30, 2023 and December 31, 2022.
On October 16, 2018, FERC issued an order on all four complaints describing how it intends to address the issues that were remanded by the Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. Initial briefs were filed by the NETOs, Complainants and FERC Trial Staff on January 11, 2019 and reply briefs were filed on March 8, 2019. The NETOs' brief was supportive of the overall ROE methodology determined in the October 16, 2018 order provided the FERC does not change the proposed methodology or alter its implementation in a manner that has a material impact on the results.
The FERC order included illustrative calculations for the first complaint using FERC's proposed frameworks with financial data from that complaint. Those illustrative calculations indicated that for the first complaint period, for the NETOs, which FERC concludes are of average financial risk, the preliminary just and reasonable base ROE is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent.
If the results of the illustrative calculations were included in a final FERC order for each of the complaint periods, then a 10.41 percent base ROE and a 13.08 percent incentive cap would not have a significant impact on our financial statements for all of the complaint periods. These preliminary calculations are not binding and do not represent what we believe to be the most likely outcome of a final FERC order.
On November 21, 2019, FERC issued Opinion No. 569 affecting the two pending transmission ROE complaints against the Midcontinent ISO (MISO) transmission owners, in which FERC adopted a new methodology for determining base ROEs. Various parties sought rehearing. On December 23, 2019, the NETOs filed supplementary materials in the NETOs' four pending cases to respond to this new methodology because of the uncertainty of the applicability to the NETOs' cases. On May 21, 2020, the FERC issued its order in Opinion No. 569-A on the rehearing of the MISO transmission owners' cases, in which FERC again changed its methodology for determining the MISO transmission owners' base ROEs. On November 19, 2020, the FERC issued Opinion No. 569-B denying rehearing of Opinion No. 569-A and reaffirmed the methodology previously adopted in Opinion No. 569-A. The new methodology differs significantly from the methodology proposed by FERC in its October 16, 2018 order to determine the NETOs' base ROEs in its four pending cases. FERC Opinion Nos. 569-A and 569-B were appealed to the Court. On August 9, 2022, the Court issued its decision vacating MISO ROE FERC Opinion Nos. 569, 569-A and 569-B and remanded to FERC to reopen the proceedings. The Court found that FERC’s development of the new return methodology was arbitrary and capricious due to FERC’s failure to offer a reasonable explanation for its decision to reintroduce the risk-premium financial model in its new methodology for calculating a just and reasonable return. At this time, Eversource cannot predict how and when FERC will address the Court’s findings on the remand of the MISO FERC opinions or any potential associated impact on the NETOs’ four pending ROE complaint cases.
Given the significant uncertainty regarding the applicability of the FERC opinions in the MISO transmission owners’ two complaint cases to the NETOs’ pending four complaint cases, Eversource concluded that there is no reasonable basis for a change to the reserve or recognized ROEs for any of the complaint periods at this time. As well, Eversource cannot reasonably estimate a range of loss for any of the four complaint proceedings at this time.
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Eversource, CL&P, NSTAR Electric and PSNH currently record revenues at the 10.57 percent base ROE and incentive cap at 11.74 percent established in the October 16, 2014 FERC order.
A change of 10 basis points to the base ROE used to establish the reserves would impact Eversource’s after-tax earnings by an average of approximately $3 million for each of the four 15-month complaint periods. Prospectively from the date of a final FERC order implementing a new base ROE, based off of estimated 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 Inquiry on ROE: On March 21, 2019, FERC issued a Notice of Inquiry (NOI) seeking comments from all stakeholders on FERC's policies for evaluating ROEs for electric public utilities, and interstate natural gas and oil pipelines. On June 26, 2019, the NETOs jointly filed comments supporting the methodology established in the FERC’s October 16, 2018 order with minor enhancements going forward. The NETOs jointly filed reply comments in the FERC ROE NOI on July 26, 2019. On May 12, 2020, the NETOs filed supplemental comments in the NOI ROE docket. At this time, Eversource cannot predict how this proceeding will affect its transmission ROEs.
FERC Notice of Inquiry and Proposed Rulemaking on Transmission Incentives: On March 21, 2019, FERC issued an NOI seeking comments on FERC's policies for implementing electric transmission incentives. On June 26, 2019, Eversource filed comments requesting that FERC retain policies that have been effective in encouraging new transmission investment and remain flexible enough to attract investment in new and emerging transmission technologies. Eversource filed reply comments on August 26, 2019. On March 20, 2020, FERC issued a Notice of Proposed Rulemaking (NOPR) on transmission incentives. The NOPR intends to revise FERC’s electric transmission incentive policies to reflect competing uses of transmission due to generation resource mix, technological innovation and shifts in load patterns. FERC proposes to grant transmission incentives based on measurable project economics and reliability benefits to consumers rather than its current project risks and challenges framework. On July 1, 2020, Eversource filed comments generally supporting the NOPR.
On April 15, 2021, FERC issued a Supplemental NOPR that proposes to eliminate the existing 50 basis point return on equity for utilities that have been participating in a regional transmission organization (RTO ROE incentive) for more than three years. On June 25, 2021, the NETOs jointly filed comments strongly opposing FERC’s proposal. On July 26, 2021, the NETOs filed Supplemental NOPR reply comments responding to various parties advocating for the elimination of the RTO Adder. If FERC issues a final order eliminating the RTO ROE incentive as proposed in the Supplemental NOPR, the estimated annual impact (using 2023 estimated rate base) on Eversource's after-tax earnings is approximately $19.5 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 nine months of 2023, changes made to the regulated companies’ rates did not have a material impact on their earnings. For further information, see "Financial Condition and Business Analysis – Regulatory Developments and Rate Matters" included in Item 7, "Management’s Discussion and Analysis of Financial Condition and Results of Operations," of the Eversource 2022 Form 10-K.
Energy Supply Retail Rates: CL&P, NSTAR Electric and PSNH each finalized full requirements energy supply procurement contracts for its customers that choose to purchase power from the electric distribution company (standard offer, basic service or default energy service, respectively) for the second half of 2023 and new energy supply rates for residential customers were established effective July 1, 2023 at CL&P and NSTAR Electric and effective August 1, 2023 at PSNH. Energy supply rates are approved by the respective state regulatory commission and are re-set every six months for residential customers. CL&P’s standard service rate for residential customers decreased to 13.82 cents per kWh effective July 1, 2023, as compared to 24.17 cents effective January 1, 2023. NSTAR Electric’s basic service rate for residential customers in eastern Massachusetts decreased to 16.08 cents per kWh and for western Massachusetts customers to 14.85 cents per kWh effective July 1, 2023, as compared to 25.78 cents and 21.99 cents effective January 1, 2023, respectively. PSNH’s default energy service rate for residential customers decreased to 12.58 cents per kWh effective August 1, 2023, as compared to 20.22 cents effective February 1, 2023. Decreases in energy supply retail rates result in decreases in both energy supply procurement revenues and purchased power expenses, with no impact on earnings.
Connecticut:
CL&P Performance Based Rate Making: On May 26, 2021, in accordance with an October 2020 Connecticut law, PURA opened a proceeding to begin to evaluate and eventually implement performance-based regulation (PBR) for electric distribution companies. PURA will conduct the proceeding in two phases. On January 25, 2023, PURA staff issued a proposal outlining a suggested portfolio of performance-based regulation elements for further exploration and implementation in the second phase of the proceeding. On April 26, 2023, PURA issued a final decision on the first phase and identified various objectives to guide PBR development and evaluate adoption of a PBR framework. The decision commenced Phase 2 by initiating three reopener dockets focused on revenue adjustment mechanisms, performance metrics and integrated distribution system planning with final decisions expected in May and August of 2024. The three reopener dockets continue to progress through the Phase 2 process. We continue to monitor developments in this proceeding, and at this time, we cannot predict the ultimate outcome of this proceeding and the resulting impact to CL&P.
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Termination of Park City Wind Power Purchase Agreement: On October 2, 2023, Park City Wind LLC and CL&P signed an agreement to terminate the Park City Wind offshore wind generation PPA, at the request of Park City Wind LLC. The termination agreement was effective on October 13, 2023, the date of PURA approval. In October 2023, Park City Wind LLC paid a termination payment of $12.9 million to CL&P resulting from the termination of the PPA, which CL&P will return to customers.
Massachusetts:
Termination of SouthCoast Wind Power Purchase Agreements: On August 28, 2023, SouthCoast Wind Energy LLC and NSTAR Electric signed agreements to terminate three SouthCoast Wind offshore wind generation PPAs, at the request of SouthCoast Wind Energy LLC. The termination agreements were effective on September 29, 2023, the date of DPU approval. In October 2023, SouthCoast Wind Energy, LLC paid a termination payment totaling $32.5 million to NSTAR Electric resulting from the termination of the PPAs, which NSTAR Electric will return to customers.
Termination of Commonwealth Wind Power Purchase Agreement: On July 13, 2023, Commonwealth Wind, LLC and NSTAR Electric signed an agreement to terminate the Commonwealth Wind offshore wind generation PPA, at the request of Commonwealth Wind, LLC. The termination agreement was effective on August 23, 2023, the date of DPU approval. In October 2023, Commonwealth Wind, LLC paid a termination payment of $25.9 million to NSTAR Electric, which NSTAR Electric will return to customers.
Critical Accounting Policies
The preparation of financial statements in conformity with GAAP requires management to make estimates, assumptions and, at times, difficult, subjective or complex judgments. Changes in these estimates, assumptions and judgments, in and of themselves, could materially impact our financial position, results of operations or cash flows. Our management discusses with the Audit Committee of our Board of Trustees significant matters relating to critical accounting policies. Our critical accounting policies that we believed were the most critical in nature were reported in the Eversource 2022 Form 10-K. There have been no material changes with regard to these critical accounting policies.
Refer to Note 1E, “Summary of Significant Accounting Policies - Investments in Unconsolidated Affiliates,” to the financial statements for further discussion of the critical accounting estimates surrounding impairment analysis.
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.
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RESULTS OF OPERATIONS – EVERSOURCE ENERGY AND SUBSIDIARIES
The following provides the amounts and variances in operating revenues and expense line items in the statements of income for Eversource for the three and nine months ended September 30, 2023 and 2022 included in this combined Quarterly Report on Form 10-Q:

| For the Three Months Ended September 30, |  | For the Nine Months Ended September 30,
(Millions of Dollars) | 2023 |  | 2022 |  | Increase/(Decrease) |  | 2023 |  | 2022 |  | Increase/(Decrease)
Operating Revenues | $ | 2,791.5 |  |  | $ | 3,215.6 |  |  | $ | (424.1) |  |  | $ | 9,216.5 |  |  | $ | 9,259.6 |  |  | $ | (43.1) |
Operating Expenses: |  |  |  |  |  |  |  |  |  |  |
Purchased Power, Purchased Natural Gas and Transmission | 1,168.6 |  |  | 1,388.0 |  |  | (219.4) |  |  | 4,232.9 |  |  | 3,718.3 |  |  | 514.6 |
Operations and Maintenance | 500.7 |  |  | 454.3 |  |  | 46.4 |  |  | 1,382.6 |  |  | 1,378.9 |  |  | 3.7 |
Depreciation | 329.5 |  |  | 302.1 |  |  | 27.4 |  |  | 962.5 |  |  | 885.7 |  |  | 76.8 |
Amortization | (144.0) |  |  | 111.3 |  |  | (255.3) |  |  | (438.5) |  |  | 418.6 |  |  | (857.1) |
Energy Efficiency Programs | 162.4 |  |  | 162.5 |  |  | (0.1) |  |  | 531.2 |  |  | 498.7 |  |  | 32.5 |
Taxes Other Than Income Taxes | 243.7 |  |  | 240.1 |  |  | 3.6 |  |  | 705.0 |  |  | 683.5 |  |  | 21.5 |
Total Operating Expenses | 2,260.9 |  |  | 2,658.3 |  |  | (397.4) |  |  | 7,375.7 |  |  | 7,583.7 |  |  | (208.0) |
Operating Income | 530.6 |  |  | 557.3 |  |  | (26.7) |  |  | 1,840.8 |  |  | 1,675.9 |  |  | 164.9 |
Interest Expense | 222.3 |  |  | 178.1 |  |  | 44.2 |  |  | 624.3 |  |  | 491.6 |  |  | 132.7 |
Impairment of Offshore Wind Investment | — |  |  | — |  |  | — |  |  | 401.0 |  |  | — |  |  | 401.0 |
Other Income, Net | 79.1 |  |  | 89.8 |  |  | (10.7) |  |  | 263.0 |  |  | 255.3 |  |  | 7.7 |
Income Before Income Tax Expense | 387.4 |  |  | 469.0 |  |  | (81.6) |  |  | 1,078.5 |  |  | 1,439.6 |  |  | (361.1) |
Income Tax Expense | 45.8 |  |  | 117.7 |  |  | (71.9) |  |  | 226.7 |  |  | 349.3 |  |  | (122.6) |
Net Income | 341.6 |  |  | 351.3 |  |  | (9.7) |  |  | 851.8 |  |  | 1,090.3 |  |  | (238.5) |
Net Income Attributable to Noncontrolling Interests | 1.9 |  |  | 1.9 |  |  | — |  |  | 5.6 |  |  | 5.6 |  |  | — |
Net Income Attributable to Common Shareholders | $ | 339.7 |  |  | $ | 349.4 |  |  | $ | (9.7) |  |  | $ | 846.2 |  |  | $ | 1,084.7 |  |  | $ | (238.5) |

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

| Electric |  | Firm Natural Gas |  | Water
| Sales Volumes (GWh) |  | Percentage Decrease |  | Sales Volumes (MMcf) |  | Percentage Decrease |  | Sales Volumes (MG) |  | Percentage Decrease
Three Months Ended September 30: | 2023 |  | 2022 |  |  | 2023 |  | 2022 |  |  | 2023 |  | 2022 |
Traditional | 2,090 |  |  | 2,140 |  |  | (2.3) | % |  | — |  |  | — |  |  | — | % |  | 469 |  |  | 596 |  |  | (21.3) | %
Decoupled and Special Contracts (1) | 12,140 |  |  | 12,545 |  |  | (3.2) | % |  | 15,755 |  |  | 15,751 |  |  | — | % |  | 7,168 |  |  | 8,379 |  |  | (14.5) | %
Total Sales Volumes | 14,230 |  |  | 14,685 |  |  | (3.1) | % |  | 15,755 |  |  | 15,751 |  |  | — | % |  | 7,637 |  |  | 8,975 |  |  | (14.9) | %
Nine Months Ended September 30: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Traditional | 5,735 |  |  | 5,927 |  |  | (3.2) | % |  | — |  |  | — |  |  | — | % |  | 1,148 |  |  | 1,227 |  |  | (6.4) | %
Decoupled and Special Contracts (1) | 31,858 |  |  | 33,358 |  |  | (4.5) | % |  | 99,289 |  |  | 109,163 |  |  | (9.0) | % |  | 17,761 |  |  | 17,965 |  |  | (1.1) | %
Total Sales Volumes | 37,593 |  |  | 39,285 |  |  | (4.3) | % |  | 99,289 |  |  | 109,163 |  |  | (9.0) | % |  | 18,909 |  |  | 19,192 |  |  | (1.5) | %

(1) Special contracts are unique to Yankee Gas natural gas distribution customers who take service under such an arrangement and generally specify the amount of distribution revenue to be paid to Yankee Gas regardless of the customers' usage.
Weather, fluctuations in energy supply costs, conservation measures (including utility-sponsored energy efficiency programs), and economic conditions affect customer energy usage and water consumption. Industrial sales volumes are less sensitive to temperature variations than residential and commercial sales volumes. In our service territories, weather impacts both electric and water sales volumes during the summer and both electric and natural gas sales volumes during the winter; however, natural gas sales volumes are more sensitive to temperature variations than electric sales volumes. Customer heating or cooling usage may not directly correlate with historical levels or with the level of degree-days that occur.
Fluctuations in retail electric sales volumes at PSNH impact earnings ("Traditional" in the table above). For CL&P, NSTAR Electric, NSTAR Gas, EGMA, Yankee Gas, and our Connecticut water distribution business, fluctuations in retail sales volumes do not materially impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms ("Decoupled" in the table above). These distribution revenues are decoupled from their customer sales volumes, which breaks the relationship between sales volumes and revenues recognized.
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Operating Revenues: The variance in Operating Revenues by segment is as follows:

(Millions of Dollars) | Three Months Ended |  | Nine Months Ended
Electric Distribution | $ | (423.8) |  |  | $ | (171.5) |
Natural Gas Distribution | (7.3) |  |  | 103.2 |
Electric Transmission | 22.8 |  |  | 68.8 |
Water Distribution | 3.5 |  |  | 8.8 |
Other | 51.2 |  |  | 154.6 |
Eliminations | (70.5) |  |  | (207.0) |
Total Operating Revenues | $ | (424.1) |  |  | $ | (43.1) |

Electric and Natural Gas Distribution Revenues:
Base Distribution Revenues:
•Base electric distribution revenues decreased $30.4 million for the three month period due primarily to a rate design change at NSTAR Electric approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues and resulted in a decrease of $42.0 million, partially offset by a base distribution rate increase effective January 1, 2023 at NSTAR Electric of $12.0 million.
•Base electric distribution revenues increased $5.6 million for the nine month period due primarily to a base distribution rate increase at NSTAR Electric effective January 1, 2023 of $29.9 million, partially offset by a rate design change at NSTAR Electric approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues and resulted in a decrease of $20.8 million. As part of the 2022 NSTAR Electric rate case decision, certain customer rates changed from seasonal demand charges to a single annual demand charge effective January 1, 2023, resulting in a shift in the timing of revenues and earnings recognized quarterly in 2023, as compared to 2022, but with no impact on an annual basis. This rate design change results in higher revenues in each of the first and fourth quarters of 2023 of approximately $21 million, offset by lower revenues in the third quarter of 2023 of approximately $42 million, as compared to the same periods in 2022.
•Base natural gas distribution revenues increased $1.6 million and $14.7 million for the respective three and nine month periods due primarily to the impact of base distribution rate increases at NSTAR Gas and EGMA effective November 1, 2022.
Tracked Distribution Revenues: Tracked distribution revenues consist of certain costs that are recovered from customers in retail rates through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs has no impact on earnings. Revenues from certain of these cost tracking mechanisms also include certain incentives earned, return on capital tracking mechanisms, and carrying charges that are billed in rates to customers, which do impact earnings. Costs recovered through cost tracking mechanisms include, among others, energy supply and natural gas supply procurement and other energy-related costs, electric retail transmission charges, energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), certain capital tracking mechanisms for infrastructure improvements, and additionally for the Massachusetts utilities, pension and PBOP benefits, net metering for distributed generation, and solar-related programs. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market, sales of natural gas to third party marketers, and the sale of RECs to various counterparties.
Customers have the choice to purchase electricity from each Eversource electric utility or from a competitive third party supplier. For customers who have contracted separately with these competitive suppliers, revenue is not recorded for the sale of the electricity commodity, as the utility is acting as an agent on behalf of the third party supplier. For customers that choose to purchase electric generation from CL&P, NSTAR Electric or PSNH, each purchases power on behalf of, and is permitted to recover the related energy supply cost without mark-up from, its customers, and records offsetting amounts in revenues and purchased power related to this energy supply procurement. CL&P, NSTAR Electric and PSNH each remain as the distribution service provider for all customers and charge a regulated rate for distribution delivery service recorded in revenues. Certain eligible natural gas customers may elect to purchase natural gas from each Eversource natural gas utility or may contract separately with a gas supply operator. Revenue is not recorded for the sale of the natural gas commodity to customers who have contracted separately with these operators, only the delivery to a customer, as the utility is acting as an agent on behalf of the gas supply operator.
Tracked distribution revenues increased/(decreased) for the three and nine month periods, due primarily to the following:

| Electric Distribution |  | Natural Gas Distribution
(Millions of Dollars) | Three Months Ended |  | Nine Months Ended |  | Three Months Ended |  | Nine Months Ended
Retail Tariff Tracked Revenues: |  |  |  |  |  |  |
Energy supply procurement | $ | (102.5) |  |  | $ | 680.0 |  |  | $ | (71.1) |  |  | $ | (42.8) |
CL&P FMCC | (75.1) |  |  | (343.4) |  |  | — |  |  | — |
Retail transmission | (48.7) |  |  | (97.2) |  |  | — |  |  | — |
Energy efficiency | (9.6) |  |  | 5.0 |  |  | 5.8 |  |  | 34.1 |
Other distribution tracking mechanisms | (4.3) |  |  | (19.4) |  |  | 5.1 |  |  | 24.3 |
Wholesale Market Sales Revenue | (162.2) |  |  | (410.8) |  |  | 48.9 |  |  | 71.2 |

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The decrease in energy supply procurement within electric distribution for the three month period was driven by lower average supply-related sales volumes, partially offset by higher average prices. The increase in energy supply procurement within electric distribution for the nine month period was driven by higher average prices, partially offset by lower average supply-related sales volumes. The decrease in energy supply procurement within natural gas distribution for the three month period was driven by lower average prices and lower average supply-related sales volumes. The decrease in energy supply procurement within natural gas distribution for the nine month period was driven by lower average supply-related sales volumes, partially offset by higher average prices.
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.
The decrease in CL&P’s FMCC revenues was driven by a decrease in the retail Non-Bypassable Federally Mandated Congestion Charge (NBFMCC) rate, which reflects the impact of returning net benefits of higher wholesale market sales received in the ISO-NE market for long-term state approved energy contracts at CL&P, which are then credited back to customers through the retail NBFMCC rate. CL&P’s average NBFMCC rate in effect from January 1, 2022 through April 30, 2022 was $0.01423 per kWh and from May 1 through August 31, 2022 was $0.01251 per kWh. As a result of the CL&P RAM proceeding in Docket No. 22-01-03, CL&P reduced the average NBFMCC rate effective September 1, 2022 from $0.01251 per kWh to $0.00000 per kWh. As part of a November 2022 rate relief plan, CL&P further reduced the average NBFMCC rate effective January 1, 2023 to a credit of $0.01524 per kWh. These rate reductions returned to customers the net revenues generated by long-term state-approved energy contracts with the Millstone and Seabrook nuclear power plants. The average NBFMCC rate changed to $0.00000 per kWh effective July 1, 2023. As a result of the 2023 CL&P RAM decision, the average NBFMCC rate changed to $0.00293 per kWh effective September 1, 2023.
The decrease in electric distribution wholesale market sales revenue for the three and nine month periods was due primarily to lower average electricity market prices received for wholesale sales at CL&P, NSTAR Electric and PSNH. ISO-NE average market prices received for CL&P’s wholesale sales decreased to an average price of $32.17 per MWh and $38.16 per MWh for the three and nine months ended September 30, 2023, respectively, as compared to $81.50 per MWh and $86.13 per MWh for the same periods in 2022, respectively, driven primarily by lower natural gas prices in New England. Volumes sold into the market were primarily from the sale of output generated by the Millstone PPA and Seabrook PPA that CL&P entered into in 2019, as required by regulation. CL&P sells the energy purchased from Millstone and Seabrook into the wholesale market and uses the proceeds from the energy sales to offset the contract costs. The net sales or net cost amount is refunded to, or recovered from, customers in the non-bypassable component of the CL&P FMCC rate.
Electric Transmission Revenues: Electric transmission revenues increased $22.8 million and $68.8 million for the three and nine month periods, respectively, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure.
Other Revenues and Eliminations: Other revenues primarily include the revenues of Eversource's service company, most of which are eliminated in consolidation. Eliminations are also primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business in rates charged to their customers.
Purchased Power, Purchased Natural Gas and Transmission expense includes costs associated with 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 |  | Nine Months Ended
Energy supply procurement costs | $ | (107.9) |  |  | $ | 670.6 |
Other electric distribution costs | (6.6) |  |  | (14.8) |
Natural gas costs | (24.8) |  |  | 3.4 |
Transmission costs | (59.0) |  |  | (90.0) |
Eliminations | (21.1) |  |  | (54.6) |
Total Purchased Power, Purchased Natural Gas and Transmission | $ | (219.4) |  |  | $ | 514.6 |

The variance in energy supply procurement costs is offset in Operating Revenues (tracked energy supply procurement revenues). The decrease in other electric distributions costs for the three and nine month periods was primarily the result of a decrease in long-term renewable contract costs and lower net metering costs at NSTAR Electric, partially offset by higher long-term contractual energy-related costs at CL&P that are recovered in the non-bypassable component of the FMCC mechanism, and by higher net metering costs at PSNH.
Costs at the natural gas distribution segment include supply procurement costs for retail customers and supply costs for wholesale third party marketers. Total natural gas costs decreased for the three month period due primarily to lower average purchased volumes and lower average prices. Total natural gas costs increased for the nine month period due primarily to an increase in the retail cost deferral, partially offset by lower average purchased volumes and lower average prices.
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The decrease in transmission costs for the three and nine month periods was primarily the result of a decrease in the retail transmission cost deferral, which reflects the actual cost of transmission service compared to estimated amounts billed to customers and a decrease in costs billed by ISO-NE that support regional grid investments. These decreases were partially offset by an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network.
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 |  | Nine Months Ended
Base Electric Distribution (Non-Tracked Costs): |  |  |
Storm costs | $ | 18.3 |  |  | $ | 8.7 |
Shared corporate costs (including computer software depreciation at Eversource Service) | 7.1 |  |  | 24.7 |
Other non-tracked operations and maintenance | 0.3 |  |  | (10.7) |
General costs (including vendor services in corporate areas, bad debt expense, insurance, fees and assessments) | 0.1 |  |  | 11.1 |
Employee-related expenses (including labor and benefits) | (0.4) |  |  | (10.2) |
Vegetation management | (0.4) |  |  | (4.1) |
Operations-related expenses (including vendor services and vehicles) | (4.6) |  |  | (3.1) |
Total Base Electric Distribution (Non-Tracked Costs) | 20.4 |  |  | 16.4 |
Tracked Electric Costs (Electric Distribution and Electric Transmission) | 18.2 |  |  | 28.1 |
Total Electric Distribution and Electric Transmission | 38.6 |  |  | 44.5 |
Natural Gas Distribution: |  |  |
Base (Non-Tracked Costs) - Three month increase due primarily to higher bad debt expense, partially offset by lower employee-related expenses; nine month decrease due primarily to lower employee-related expenses | 4.0 |  |  | (6.8) |
Tracked Costs | 1.1 |  |  | (0.9) |
Total Natural Gas Distribution | 5.1 |  |  | (7.7) |
Water Distribution | 1.7 |  |  | 3.9 |
Eversource Parent and Other Companies - other operations and maintenance | 52.4 |  |  | 130.3 |
Eliminations | (48.6) |  |  | (152.4) |
Transaction and Transition Costs | (2.8) |  |  | (14.9) |
Total Operations and Maintenance | $ | 46.4 |  |  | $ | 3.7 |

Depreciation expense increased for the three and nine month periods due primarily to higher utility plant in service balances, partially offset by a decrease in approved depreciation rates as part of the rate case decision effective January 1, 2023 at NSTAR Electric.
Amortization expense includes the deferral of energy-related costs and other costs that are included in certain regulatory commission-approved cost tracking mechanisms. This deferral adjusts expense to match the corresponding revenues compared to the actual costs incurred. These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of certain costs as those costs are collected in rates.
Amortization decreased for the three and nine month periods due primarily to the deferral adjustment of energy-related and other tracked costs at CL&P (included in the non-bypassable component of the FMCC mechanism), NSTAR Electric and PSNH, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The decrease in the CL&P FMCC mechanism was driven primarily by the November 2022 rate relief plan, which reduced the non-bypassable FMCC rate effective January 1, 2023. The reduction in the CL&P non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $210.3 million in the three month period and $717.3 million in the nine month period. The nine month decrease was also driven by the impact of a new regulatory tracking mechanism at PSNH that allows for the recovery of 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.
The decreases for the three and nine month periods were partially offset by the amortization of historical exogenous property taxes that were approved for recovery effective January 1, 2023 at NSTAR Electric and effective November 1, 2022 at NSTAR Gas and EGMA, and an unfavorable regulatory adjustment resulting from NSTAR Gas’ GSEP reconciliation filing that resulted in an increase to amortization expense of $9.0 million recorded in the third quarter of 2023.
Energy Efficiency Programs expense increased for the nine month period due primarily to the deferral adjustment at NSTAR Gas and EGMA, which reflects the actual costs of energy efficiency programs compared to the amounts billed to customers, and the timing of the recovery of energy efficiency costs. The costs for the majority of the state energy policy initiatives and expanded energy efficiency programs are recovered from customers in rates and have no impact on earnings.
Taxes Other Than Income Taxes expense increased for the three month period due primarily to higher employment-related taxes based on the timing of payroll pay periods. For the nine month period, the increase was due primarily to higher employment-related taxes based on the timing of payroll pay periods, higher Connecticut gross earnings taxes, and higher property taxes as a result of higher utility plant balances.
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Interest Expense increased for the three and nine month periods due primarily to an increase in interest on long-term debt as a result of new debt issuances ($46.5 million and $149.0 million, respectively), an increase in interest on short-term notes payable ($11.8 million and $31.5 million, respectively), an increase in interest expense on regulatory deferrals ($4.3 million and $8.2 million, respectively), and higher amortization of debt discounts and premiums, net ($0.1 million and $2.5 million, respectively), partially offset by an increase in capitalized AFUDC related to debt funds and other capitalized interest ($18.8 million and $51.0 million, respectively), and a decrease in RRB interest expense ($0.3 million and $1.0 million, respectively).
Impairment of Offshore Wind Investment relates to an impairment charge in the second quarter of 2023 associated with Eversource’s equity method investment in its offshore wind business resulting from the completion of the strategic review of its offshore wind investment portfolio. See "Business Development and Capital Expenditures – Offshore Wind Business" included in this Management's Discussion and Analysis of Financial Condition and Results of Operations.
Other Income, Net decreased for the three month period due primarily to a decrease related to pension, SERP and PBOP non-service income components ($26.8 million), the absence in 2023 of a gain on sale of property in 2022 ($2.5 million), and a decrease in equity in earnings related to Eversource's equity method investments ($1.1 million), partially offset by an increase in interest income primarily from regulatory deferrals ($10.0 million), an increase in capitalized AFUDC related to equity funds ($8.4 million), and higher investment income driven by market volatility ($1.4 million).
Other Income, Net increased for the nine month period due primarily to an increase in interest income primarily from regulatory deferrals ($38.3 million) and an increase in capitalized AFUDC related to equity funds ($21.8 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($67.9 million), a decrease in equity in earnings related to Eversource's equity method investments ($9.3 million), a loss on the disposition of land in 2023 compared to gains on the sales of property in 2022 ($9.2 million), and investment losses in 2023 compared to investment income in 2022 driven by market volatility ($2.8 million). Other Income, Net also increased for the nine month period due to a benefit in both the first and second quarters 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 decreased for the three month period due primarily to lower pre-tax earnings ($17.1 million), lower state taxes ($9.2 million), and lower return to provision adjustments ($66.7 million), partially offset by a decrease in amortization of EDIT ($1.3 million), an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($5.7 million), lower share-based payment excess tax benefits ($0.1 million), and an increase in reserves ($14.0 million, of which $8.8 million relates to an uncertain tax position).
Income Tax Expense decreased for the nine month period due primarily to lower pre-tax earnings ($75.8 million), lower state taxes ($37.6 million), a decrease in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($6.1 million), and lower return to provision adjustments ($66.7 million), partially offset by lower share-based payment excess tax benefits ($2.6 million), a decrease in amortization of EDIT ($4.1 million) and an increase in reserves ($56.9 million) primarily related to the impairment of Eversource’s offshore wind investment valuation allowance reserve of $40 million and $8.8 million relating to an uncertain tax position.
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RESULTS OF OPERATIONS –
THE CONNECTICUT LIGHT AND POWER COMPANY
NSTAR ELECTRIC COMPANY AND SUBSIDIARY
PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES
The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P, NSTAR Electric and PSNH for the nine months ended September 30, 2023 and 2022 included in this combined Quarterly Report on Form 10-Q:

| For the Nine Months Ended September 30,
| CL&P |  | NSTAR Electric |  | PSNH
(Millions of Dollars) | 2023 |  | 2022 |  | Increase/ (Decrease) |  | 2023 |  | 2022 |  | Increase/ (Decrease) |  | 2023 |  | 2022 |  | Increase/ (Decrease)
Operating Revenues | $ | 3,563.1 |  |  | $ | 3,690.6 |  |  | $ | (127.5) |  |  | $ | 2,728.8 |  |  | $ | 2,752.3 |  |  | $ | (23.5) |  |  | $ | 1,123.3 |  |  | $ | 1,077.1 |  |  | $ | 46.2 |
Operating Expenses: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Purchased Power and Transmission | 2,136.9 |  |  | 1,585.5 |  |  | 551.4 |  |  | 936.5 |  |  | 971.8 |  |  | (35.3) |  |  | 499.6 |  |  | 452.0 |  |  | 47.6 |
Operations and Maintenance | 525.7 |  |  | 515.9 |  |  | 9.8 |  |  | 487.0 |  |  | 475.7 |  |  | 11.3 |  |  | 217.5 |  |  | 194.1 |  |  | 23.4 |
Depreciation | 281.1 |  |  | 265.0 |  |  | 16.1 |  |  | 277.4 |  |  | 269.9 |  |  | 7.5 |  |  | 104.3 |  |  | 95.0 |  |  | 9.3 |
Amortization of Regulatory (Liabilities)/Assets, Net | (425.4) |  |  | 318.3 |  |  | (743.7) |  |  | 14.9 |  |  | 65.3 |  |  | (50.4) |  |  | (35.2) |  |  | 43.4 |  |  | (78.6) |
Energy Efficiency Programs | 100.7 |  |  | 103.1 |  |  | (2.4) |  |  | 252.3 |  |  | 255.2 |  |  | (2.9) |  |  | 30.5 |  |  | 28.7 |  |  | 1.8 |
Taxes Other Than Income Taxes | 303.2 |  |  | 290.5 |  |  | 12.7 |  |  | 188.2 |  |  | 185.8 |  |  | 2.4 |  |  | 73.3 |  |  | 73.4 |  |  | (0.1) |
Total Operating Expenses | 2,922.2 |  |  | 3,078.3 |  |  | (156.1) |  |  | 2,156.3 |  |  | 2,223.7 |  |  | (67.4) |  |  | 890.0 |  |  | 886.6 |  |  | 3.4 |
Operating Income | 640.9 |  |  | 612.3 |  |  | 28.6 |  |  | 572.5 |  |  | 528.6 |  |  | 43.9 |  |  | 233.3 |  |  | 190.5 |  |  | 42.8 |
Interest Expense | 145.4 |  |  | 125.2 |  |  | 20.2 |  |  | 139.8 |  |  | 119.0 |  |  | 20.8 |  |  | 55.9 |  |  | 43.4 |  |  | 12.5 |
Other Income, Net | 46.6 |  |  | 61.3 |  |  | (14.7) |  |  | 120.7 |  |  | 101.4 |  |  | 19.3 |  |  | 19.2 |  |  | 23.4 |  |  | (4.2) |
Income Before Income Tax Expense | 542.1 |  |  | 548.4 |  |  | (6.3) |  |  | 553.4 |  |  | 511.0 |  |  | 42.4 |  |  | 196.6 |  |  | 170.5 |  |  | 26.1 |
Income Tax Expense | 141.0 |  |  | 126.3 |  |  | 14.7 |  |  | 120.1 |  |  | 110.7 |  |  | 9.4 |  |  | 44.6 |  |  | 36.4 |  |  | 8.2 |
Net Income | $ | 401.1 |  |  | $ | 422.1 |  |  | $ | (21.0) |  |  | $ | 433.3 |  |  | $ | 400.3 |  |  | $ | 33.0 |  |  | $ | 152.0 |  |  | $ | 134.1 |  |  | $ | 17.9 |

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

| For the Nine Months Ended September 30,
| 2023 |  | 2022 |  |  |  | Percentage Decrease
CL&P | 14,830 |  |  | 15,781 |  |  |  |  | (6.0) | %
NSTAR Electric | 17,028 |  |  | 17,577 |  |  |  |  | (3.1) | %
PSNH | 5,735 |  |  | 5,927 |  |  |  |  | (3.2) | %

Fluctuations in retail electric sales volumes at PSNH impact earnings. For CL&P and NSTAR Electric, fluctuations in retail electric sales volumes do not impact earnings due to their respective regulatory commission-approved distribution revenue decoupling mechanisms.
Operating Revenues: Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased $127.5 million at CL&P and $23.5 million at NSTAR Electric, and increased $46.2 million at PSNH for the nine month period.
Base Distribution Revenues:
•CL&P's distribution revenues were flat.
•NSTAR Electric's distribution revenues increased $9.1 million in the nine month period due primarily to a base distribution rate increase effective January 1, 2023 of $29.9 million, partially offset by a rate design change approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues and resulted in a decrease of $20.8 million. As part of the 2022 NSTAR Electric rate case decision, certain customer rates changed from seasonal demand charges to a single annual demand charge effective January 1, 2023, resulting in a shift in the timing of revenues and earnings recognized quarterly in 2023, as compared to 2022, but with no impact on an annual basis. This rate design change results in higher revenues in each of the first and fourth quarters of 2023 of approximately $21 million, offset by lower revenues in the third quarter of 2023 of approximately $42 million, as compared to the same periods in 2022.
•PSNH's distribution revenues decreased $3.5 million due primarily to a decrease in sales volumes as a result of milder weather in 2023 compared to 2022.
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Tracked Distribution Revenues: Tracked distribution revenues consist of certain costs that are recovered from customers in retail rates through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs has no impact on earnings. Revenues from certain of these cost tracking mechanisms also include certain incentives earned, return on capital tracking mechanisms, and carrying charges that are billed in rates to customers, which do impact earnings. Costs recovered through cost tracking mechanisms include, among others, energy supply procurement and other energy-related costs, retail transmission charges, energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), certain capital tracking mechanisms for infrastructure improvements, and additionally for NSTAR Electric, pension and PBOP benefits, net metering for distributed generation, and solar-related programs. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties.
Customers have the choice to purchase electricity from each Eversource electric utility or from a competitive third party supplier. For customers who have contracted separately with these competitive suppliers, revenue is not recorded for the sale of the electricity commodity, as the utility is acting as an agent on behalf of the third party supplier. For customers that choose to purchase electric generation from CL&P, NSTAR Electric or PSNH, each purchases power on behalf of, and is permitted to recover the related energy supply cost without mark-up from, its customers, and records offsetting amounts in revenues and purchased power related to this energy supply procurement. CL&P, NSTAR Electric and PSNH each remain as the distribution service provider for all customers and charge a regulated rate for distribution delivery service recorded in revenues.
Tracked distribution revenues increased/(decreased) for the nine month period, due primarily to the following:

(Millions of Dollars) | CL&P |  | NSTAR Electric |  | PSNH
Retail Tariff Tracked Revenues: |  |  |  |  |
Energy supply procurement | $ | 489.4 |  |  | $ | 144.7 |  |  | $ | 45.9 |
CL&P FMCC | (343.4) |  |  | — |  |  | — |
Retail transmission | 21.6 |  |  | (86.7) |  |  | (32.1) |
Other distribution tracking mechanisms | 13.7 |  |  | (44.3) |  |  | 16.2 |
Wholesale Market Sales Revenue | (325.9) |  |  | (61.0) |  |  | (23.9) |

The increase in energy supply procurement at CL&P, NSTAR Electric and PSNH was driven by higher average prices, partially offset by lower average supply-related sales volumes.
Fluctuations in retail transmission revenues are driven by the recovery of the costs of our wholesale transmission business, such as those billed by ISO-NE and Local and Regional Network Service charges. For further information, see "Purchased Power and Transmission Expense" below.
The decrease in CL&P’s FMCC revenues was driven by a decrease in the retail Non-Bypassable Federally Mandated Congestion Charge (NBFMCC) rate, which reflects the impact of returning net benefits of higher wholesale market sales received in the ISO-NE market for long-term state approved energy contracts at CL&P, which are then credited back to customers through the retail NBFMCC rate. CL&P’s average NBFMCC rate in effect from January 1, 2022 through April 30, 2022 was $0.01423 per kWh and from May 1 through August 31, 2022 was $0.01251 per kWh. As a result of the CL&P RAM proceeding in Docket No. 22-01-03, CL&P reduced the average NBFMCC rate effective September 1, 2022 from $0.01251 per kWh to $0.00000 per kWh. As part of a November 2022 rate relief plan, CL&P further reduced the average NBFMCC rate effective January 1, 2023 to a credit of $0.01524 per kWh. These rate reductions returned to customers the net revenues generated by long-term state-approved energy contracts with the Millstone and Seabrook nuclear power plants. The average NBFMCC rate changed to $0.00000 per kWh effective July 1, 2023. As a result of the 2023 CL&P RAM decision, the average NBFMCC rate changed to $0.00293 per kWh effective September 1, 2023.
The decrease in wholesale market sales revenue for the nine month period was due primarily to lower average electricity market prices received for wholesale sales at CL&P, NSTAR Electric and PSNH. ISO-NE average market prices received for CL&P’s wholesale sales decreased to an average price of $38.16 per MWh for the nine months ended September 30, 2023, as compared to $86.13 per MWh for the same period in 2022, driven primarily by lower natural gas prices in New England. CL&P’s volumes sold into the market were primarily from the sale of output generated by the Millstone PPA and Seabrook PPA that CL&P entered into in 2019, as required by regulation. CL&P sells the energy purchased from Millstone and Seabrook into the wholesale market and uses the proceeds from the energy sales to offset the contract costs. The net sales or net cost amount is refunded to, or recovered from, customers in the non-bypassable component of the CL&P FMCC rate.
Transmission Revenues: Transmission revenues increased $10.6 million at CL&P, $20.5 million at NSTAR Electric, and $37.7 million at PSNH for the nine month period, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure.
Eliminations: Eliminations are primarily related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business in rates charged to their customers. The impact of eliminations increased revenues by $5.5 million at CL&P and $2.1 million at PSNH and decreased revenues by $8.1 million at NSTAR Electric for the nine 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, 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 | $ | 484.2 |  |  | $ | 142.1 |  |  | $ | 44.3 |
Other electric distribution costs | 37.4 |  |  | (82.4) |  |  | 30.2 |
Transmission costs | 25.8 |  |  | (86.8) |  |  | (29.0) |
Eliminations | 4.0 |  |  | (8.2) |  |  | 2.1 |
Total Purchased Power and Transmission | $ | 551.4 |  |  | $ | (35.3) |  |  | $ | 47.6 |

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 CL&P is due to higher long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism, at NSTAR Electric is due to a decrease in long-term renewable contract costs and a decrease in net metering costs, and at PSNH is due primarily to higher net-metering costs.
Included in transmission costs are charges that recover the cost of transporting electricity over high-voltage lines from generation facilities to substations, including costs allocated by ISO-NE to maintain the wholesale electric market.
•The increase in transmission costs at CL&P was due primarily to an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network and an increase resulting from the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers. These were partially offset by a decrease in costs billed by ISO-NE that support regional investments.
•The decrease in transmission costs at NSTAR Electric and PSNH was due primarily to a decrease resulting from the retail transmission cost deferral and a decrease in costs billed by ISO-NE. These were partially offset by an increase in Local Network Service charges.
Operations and Maintenance expense includes tracked costs and costs that are part of base distribution rates with changes impacting earnings (non-tracked costs). 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 | $ | 11.3 |  |  | $ | 0.4 |  |  | $ | (3.0) |
Shared corporate costs (including computer software depreciation at Eversource Service) | 8.1 |  |  | 13.9 |  |  | 2.7 |
General costs (including vendor services in corporate areas, bad debt expense, insurance, fees and assessments) | 1.3 |  |  | 5.7 |  |  | 4.1 |
Vegetation management | (2.8) |  |  | 2.0 |  |  | (3.3) |
Other non-tracked operations and maintenance | (3.2) |  |  | (5.3) |  |  | (2.2) |
Operations-related expenses (including vendor services and vehicles) | (4.6) |  |  | 0.1 |  |  | 1.4 |
Employee-related expenses (including labor and benefits) | (4.9) |  |  | (6.0) |  |  | 0.7 |
Total Base Electric Distribution (Non-Tracked Costs) | 5.2 |  |  | 10.8 |  |  | 0.4 |
Tracked Costs: |  |  |  |  |
Transmission expenses | (7.4) |  |  | 0.3 |  |  | 2.0 |
Other tracked operations and maintenance | 12.0 |  |  | 0.2 |  |  | 21.0 |
Total Tracked Costs | 4.6 |  |  | 0.5 |  |  | 23.0 |
Total Operations and Maintenance | $ | 9.8 |  |  | $ | 11.3 |  |  | $ | 23.4 |

Depreciation expense increased for the nine month period for CL&P, NSTAR Electric and PSNH due to higher net plant in service balances. The increase at NSTAR Electric was partially offset by a decrease in approved depreciation rates as part of the rate case decision effective January 1, 2023.
Amortization of Regulatory (Liabilities)/Assets, Net expense includes the deferral of energy-related costs and other costs that are included in certain regulatory commission-approved cost tracking mechanisms. This deferral adjusts expense to match the corresponding revenues compared to the actual costs incurred. These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of certain costs as those costs are collected in rates. Amortization of Regulatory (Liabilities)/Assets, Net decreased for the nine month period due primarily to the following:
•The decrease at CL&P was due primarily to the deferral adjustment of energy-related and other tracked costs that are included in the non-bypassable component of the FMCC mechanism, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The decrease in the FMCC mechanism was driven primarily by the CL&P November 2022 rate relief plan, which reduced the non-bypassable FMCC rate effective January 1, 2023. The reduction in the CL&P non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $717.3 million in the nine month period.
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•The decrease at NSTAR Electric was due to the deferral adjustment of energy-related costs and other tracked costs, partially offset by an increase due to the amortization of historical exogenous property taxes that were approved for recovery effective January 1, 2023 in the November 2022 NSTAR Electric distribution rate case decision.
•The decrease at PSNH was due to the deferral adjustment of energy-related and other tracked costs, as well as the impact of a new regulatory tracking mechanism at PSNH that allows for the recovery of 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.
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. The variance in Energy Efficiency Programs expense for the nine month period is due primarily to the following:
•The decreases at CL&P and NSTAR Electric were due to the deferral adjustment, which reflects actual costs of energy efficiency programs compared to the estimated amounts billed to customers, and the timing of the recovery of energy efficiency costs.
•The increase at PSNH was due to the deferral adjustment and the timing of the recovery of energy efficiency costs.
Taxes Other Than Income Taxes increased at CL&P and NSTAR Electric for the nine month period, due primarily to higher employment-related taxes based on the timing of payroll pay periods. The increase at CL&P is also due to higher property taxes as a result of higher utility plant balances and higher Connecticut gross earnings taxes.
Interest Expense increased for the nine month period due primarily to the following:
•The increase at CL&P was due to higher interest on long-term debt ($15.4 million), higher interest on short-term notes payable ($6.4 million), and an increase in interest expense on regulatory deferrals ($1.7 million), partially offset by an increase in capitalized AFUDC related to debt funds ($2.3 million) and lower amortization of debt discounts and premiums, net ($0.2 million).
•The increase at NSTAR Electric was due to higher interest on long-term debt ($14.7 million), higher interest on short-term notes payable ($6.5 million), and an increase in interest expense on regulatory deferrals ($6.0 million), partially offset by an increase in capitalized AFUDC related to debt funds ($5.0 million).
•The increase at PSNH was due to higher interest on long-term debt ($11.4 million) and higher interest on short-term notes payable ($4.3 million), partially offset by an increase in capitalized AFUDC related to debt funds ($2.6 million) and a decrease i n RRB interest expense ($1.0 million).
Other Income, Net changed for the nine month period due primarily to the following:
•The decrease at CL&P was due primarily to a decrease related to pension, SERP and PBOP non-service income components ($23.4 million), partially offset by an increase in capitalized AFUDC related to equity funds ($4.6 million), an increase in interest income primarily on regulatory deferrals ($3.4 million) and lower investment losses driven by market volatility ($0.7 million).
•The increase at NSTAR Electric was due primarily to an increase in interest income primarily on regulatory deferrals ($25.2 million), and an increase in capitalized AFUDC related to equity funds ($16.5 million), partially offset by a decrease related to pension, SERP and PBOP non-service income components ($22.3 million) and lower investment income driven by market volatility ($0.1 million).
•The decrease at PSNH was due primarily to a decrease related to pension, SERP and PBOP non-service income components ($8.3 million) and lower investment income driven by market volatility ($0.5 million), partially offset by an increase in interest income primarily on regulatory deferrals ($2.5 million) and an increase in capitalized AFUDC related to equity funds ($1.7 million).
Income Tax Expense increased for the nine month period due primarily to the following:
•The increase at CL&P was due primarily to higher return to provision adjustments ($7.2 million), lower share-based payment excess tax benefits ($0.9 million), higher state taxes ($0.8 million), and an increase in valuation allowances ($7.8 million), partially offset by lower pre-tax earnings ($1.3 million), an increase in amortization of EDIT ($0.2 million), and a decrease in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.5 million).
•The increase at NSTAR Electric was due primarily to higher pre-tax earnings ($8.9 million), higher state taxes ($0.8 million), lower share-based payment excess tax benefits ($1.0 million), and a decrease in amortization of EDIT ($2.0 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 ($3.3 million).
•The increase at PSNH was due primarily to higher pre-tax earnings ($5.5 million), higher state taxes ($1.4 million), a decrease in amortization of EDIT ($1.6 million), and an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.2 million), partially offset by lower return to provision adjustments ($0.5 million).
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EARNINGS SUMMARY
CL&P's earnings decreased $21.0 million for the nine month period due primarily to a higher effective tax rate, higher interest expense, higher operations and maintenance expense, higher depreciation expense, and higher property and other tax expense. The earnings decrease was partially offset by higher earnings from its capital tracking mechanism due to increased electric system improvements.
NSTAR Electric's earnings increased $33.0 million for the nine month period due primarily to higher revenues as a result of the base distribution rate increase effective January 1, 2023, an increase in interest income primarily on regulatory deferrals, an increase in transmission earnings driven by a higher transmission rate base, and higher AFUDC equity income. The earnings increase was partially offset by the rate design change approved by the DPU in the 2022 rate case that shifted the recovery of quarterly revenues, higher property and other tax expense, higher interest expense, higher operations and maintenance expense, and higher depreciation expense.
PSNH's earnings increased $17.9 million for the nine month period due primarily to the impact of a new regulatory tracking mechanism at PSNH that allows for the recovery of previously incurred operating expenses associated with poles acquired on May 1, 2023 and an increase in transmission earnings driven by a higher transmission rate base. The earnings increase was partially offset by higher interest expense and lower sales volumes.
LIQUIDITY
Cash Flows: CL&P had cash flows provided by operating activities of $320.0 million for the nine months ended September 30, 2023, as compared to $554.3 million in the same period of 2022. The decrease in operating cash flows was due primarily to an increase in regulatory under-recoveries driven primarily by the timing of collections for the non-bypassable FMCC, the SBC and other regulatory tracking mechanisms, and the timing of cash payments made on our accounts payable. In 2023, CL&P increased the flow back to customers of net revenues generated by long-term state-approved energy contracts by providing these credits to customers through the non-bypassable FMCC retail rate. The reduction in the non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $717.3 million in the first nine months of 2023, as compared to the first nine months of 2022, and is presented as a cash outflow in Amortization of Regulatory (Liabilities)/Assets on the statement of cash flows. The impact of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory (Liabilities)/Assets on the statements of cash flows. These unfavorable impacts were partially offset by the timing of cash collections on our accounts receivable, a $123.0 million increase in operating cash flows due to income tax refunds received in 2023 compared to income tax payments in 2022, the absence in 2023 of $72.0 million of customer credits distributed in 2022 as a result of the October 2021 settlement agreement and the 2021 storm performance penalty for CL&P’s response to Tropical Storm Isaias, a $43.2 million decrease in cash payments for storm costs, and the timing of other working capital items.
NSTAR Electric had cash flows provided by operating activities of $529.0 million for the nine months ended September 30, 2023, as compared to $634.6 million in the same period of 2022. The decrease in operating cash flows was due primarily to an increase in regulatory under-recoveries driven by the timing of collections for regulatory tracking mechanisms including transmission, net metering, long-term renewable contracts and transition costs, the timing of other working capital items, a $32.1 million decrease in income tax refunds received in 2023 compared to 2022, an increase in cost of removal expenditures, the timing of cash collections on our accounts receivable, and the timing of cash payments made on our accounts payable. The impact of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Assets on the statements of cash flows. These unfavorable impacts were partially offset by the absence in 2023 of $76.1 million of payments in 2022 related to withheld property taxes, a $75.6 million decrease in cash payments for storm costs, and the absence in 2023 of pension contributions of $15.0 million made in 2022.
PSNH had cash flows used in operating activities of $12.9 million for the nine months ended September 30, 2023, as compared to cash flows provided by operating activities of $246.7 million in the same period of 2022. The decrease in operating cash flows was due primarily to an increase in regulatory under-recoveries driven by the timing of collections for regulatory tracking mechanisms including energy supply, stranded costs, retail transmission and wholesale transmission, a $106.1 million increase in cash payments for storm costs, the timing of cash payments made on our accounts payable, the timing of other working capital items, and an increase in cost of removal expenditures. The impact of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory (Liabilities)/Assets on the statements of cash flows. These unfavorable impacts were partially offset by a $107.3 million increase in operating cash flows due to income tax refunds received in 2023 compared to income tax payments in 2022, and the timing of cash collections on our accounts receivable.
For further information on CL&P's, NSTAR Electric's and PSNH's liquidity and capital resources, see "Liquidity" and "Business Development and Capital Expenditures" included in this Management's Discussion and Analysis of Financial Condition and Results of Operations.
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RESULTS OF OPERATIONS – THE CONNECTICUT LIGHT AND POWER COMPANY
The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P for the three months ended September 30, 2023 and 2022 included in this combined Quarterly Report on Form 10-Q:

| For the Three Months Ended September 30,
(Millions of Dollars) | 2023 |  | 2022 |  | Increase/(Decrease)
Operating Revenues | $ | 1,190.1 |  |  | $ | 1,369.1 |  |  | $ | (179.0) |
Operating Expenses: |  |  |  |  |
Purchased Power and Transmission | 660.0 |  |  | 641.1 |  |  | 18.9 |
Operations and Maintenance | 198.8 |  |  | 189.9 |  |  | 8.9 |
Depreciation | 95.2 |  |  | 89.5 |  |  | 5.7 |
Amortization of Regulatory (Liabilities)/Assets, Net | (113.2) |  |  | 105.8 |  |  | (219.0) |
Energy Efficiency Programs | 39.9 |  |  | 37.9 |  |  | 2.0 |
Taxes Other Than Income Taxes | 107.0 |  |  | 104.2 |  |  | 2.8 |
Total Operating Expenses | 987.7 |  |  | 1,168.4 |  |  | (180.7) |
Operating Income | 202.4 |  |  | 200.7 |  |  | 1.7 |
Interest Expense | 52.5 |  |  | 42.4 |  |  | 10.1 |
Other Income, Net | 18.3 |  |  | 21.9 |  |  | (3.6) |
Income Before Income Tax Expense | 168.2 |  |  | 180.2 |  |  | (12.0) |
Income Tax Expense | 48.8 |  |  | 36.9 |  |  | 11.9 |
Net Income | $ | 119.4 |  |  | $ | 143.3 |  |  | $ | (23.9) |

Operating Revenues
Sales Volumes: CL&P's retail electric GWh sales volumes were 5,692 and 5,862 for the three months ended September 30, 2023 and 2022, respectively, resulting in a decrease of 2.9 percent. Fluctuations in retail electric sales volumes do not impact earnings due to its PURA-approved distribution revenue decoupling mechanism.
Operating Revenues: Operating Revenues, which consist of base distribution revenues and tracked revenues further described below, decreased $179.0 million for the three month period.
Base Distribution Revenues: CL&P's base distribution revenues were flat.
Tracked Revenues: Tracked revenues increased/(decreased) for the three month period, due primarily to the following:

(Millions of Dollars) |
Retail Tariff Tracked Revenues: |
FMCC | $ | (75.1) |
Retail transmission | 12.0 |
Other distribution tracking mechanisms | 4.2 |
Wholesale Market Sales Revenue | (120.1) |

Fluctuations in retail transmission revenues are driven by the recovery of the costs of our wholesale transmission business, such as those billed by ISO-NE and Local and Regional Network Service charges. For further information, see "Purchased Power and Transmission Expense" below.
The decrease in CL&P’s FMCC revenues was driven by a decrease in the retail Non-Bypassable Federally Mandated Congestion Charge (NBFMCC) rate, which reflects the impact of returning net benefits of higher wholesale market sales received in the ISO-NE market for long-term state approved energy contracts at CL&P, which are then credited back to customers through the retail NBFMCC rate. CL&P’s average NBFMCC rate in effect from January 1, 2022 through April 30, 2022 was $0.01423 per kWh and from May 1 through August 31, 2022 was $0.01251 per kWh. As a result of the CL&P RAM proceeding in Docket No. 22-01-03, CL&P reduced the average NBFMCC rate effective September 1, 2022 from $0.01251 per kWh to $0.00000 per kWh. As part of a November 2022 rate relief plan, CL&P further reduced the average NBFMCC rate effective January 1, 2023 to a credit of $0.01524 per kWh. These rate reductions returned to customers the net revenues generated by long-term state-approved energy contracts with the Millstone and Seabrook nuclear power plants. The average NBFMCC rate changed to $0.00000 per kWh effective July 1, 2023. As a result of the 2023 CL&P RAM decision, the average NBFMCC rate changed to $0.00293 per kWh effective September 1, 2023.
The decrease in wholesale market sales revenue for the three month period was due primarily to lower average electricity market prices received for wholesale sales. ISO-NE average market prices received for CL&P’s wholesale sales decreased to an average price of $32.17 per MWh for the three months ended September 30, 2023, as compared to $81.50 per MWh for the same period in 2022, driven primarily by lower natural gas prices in New England. CL&P’s volumes sold into the market were primarily from the sale of output generated by the Millstone PPA and Seabrook PPA that CL&P entered into in 2019, as required by regulation. CL&P sells the energy purchased from Millstone and Seabrook into the wholesale market and uses the proceeds from the energy sales to offset the contract costs. The net sales or net cost amount is refunded to, or recovered from, customers in the non-bypassable component of the CL&P FMCC rate.
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Transmission Revenues: Transmission revenues increased $2.3 million due primarily to a higher transmission rate base as a result of continued investment in our transmission infrastructure.
Eliminations: Eliminations are primarily related to transmission revenues derived from ISO-NE regional transmission charges to the distribution business that recover the costs of the wholesale transmission business in rates charged to customers. The impact of eliminations decreased revenues by $3.3 million.
Purchased Power and Transmission expense includes costs associated with providing electric generation service supply to all CL&P 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, other energy-related costs, and transmission costs are recovered from customers in PURA-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) |
Energy supply procurement costs | $ | (7.2) |
Other distribution costs | 23.7 |
Transmission costs | 5.7 |
Eliminations | (3.3) |
Total Purchased Power and Transmission | $ | 18.9 |

The variance in energy supply procurement costs is offset in Operating Revenues (tracked energy supply procurement revenues). The increase in other distribution costs was due to higher long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism. The increase in transmission costs was due primarily to an increase resulting from the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers and an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network. These were partially offset by a decrease in costs billed by ISO-NE that support regional investments.
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) |
Base Electric Distribution (Non-Tracked Costs): |
Storm costs | $ | 14.7 |
Vegetation management | 3.9 |
Shared corporate costs (including computer software depreciation at Eversource Service) | 2.4 |
Operations-related expenses (including employee-related expenses, including labor and benefits, vendor services and vehicles) | (3.7) |
General costs (including vendor services in corporate areas, bad debt expense, insurance, fees and assessments) | (3.3) |
Other non-tracked operations and maintenance | 0.6 |
Total Base Electric Distribution (Non-Tracked Costs) | 14.6 |
Total Tracked Costs | (5.7) |
Total Operations and Maintenance | $ | 8.9 |

Depreciation expense increased for the three month period due primarily to a higher net plant in service balance.
Amortization of Regulatory (Liabilities)/Assets, Net expense includes the deferral of energy-related costs and other costs that are included in certain regulatory-approved cost tracking mechanisms. This deferral adjusts expense to match the corresponding revenues compared to the actual costs incurred. These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of certain costs as those costs are collected in rates. Amortization of Regulatory (Liabilities)/Assets, Net decreased for the three month period due primarily to the deferral adjustment of energy-related and other tracked costs that are included in the non-bypassable component of the FMCC mechanism, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The decrease in the FMCC mechanism was driven primarily by the CL&P November 2022 rate relief plan, which reduced the non-bypassable FMCC rate effective January 1, 2023. The reduction in the CL&P non-bypassable FMCC retail rate decreased the regulatory over-recovery balance, which resulted in a decrease to amortization expense of $210.3 million in the three month period.
Energy Efficiency Programs expense includes costs of various state energy policy initiatives and expanded energy efficiency programs that are recovered from customers in rates, most of which have no impact on earnings. Energy Efficiency Programs expense increased for the three month period due to the deferral adjustment, which reflects actual costs of energy efficiency programs compared to the estimated amounts billed to customers, and the timing of the recovery of energy efficiency costs.
Taxes Other Than Income Taxes increased at CL&P for the three month period due primarily to higher employment-related taxes based on the timing of payroll pay periods and higher Connecticut gross earnings taxes.
Interest Expense increased for the three month period due primarily to higher interest on long-term debt ($7.5 million), an increase in interest expense on regulatory deferrals ($1.6 million), and higher interest on short-term notes payable ($1.6 million), partially offset by an increase in capitalized AFUDC related to debt funds ($0.6 million).
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Other Income, Net decreased for the three month period due primarily to a decrease related to pension, SERP and PBOP non-service income components ($9.2 million), partially offset by an increase in interest income primarily from regulatory deferrals ($2.8 million), an increase in capitalized AFUDC related to equity funds ($1.5 million) and higher investment income driven by market volatility ($1.3 million).
Income Tax Expense increased for the three month period due primarily to an increase in valuation allowances ($5.0 million), higher return to provision adjustments ($7.2 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), partially offset by lower pre-tax earnings ($2.5 million) and lower state taxes ($0.5 million).
EARNINGS SUMMARY
CL&P's earnings decreased $23.9 million for the three month period due primarily to a higher effective tax rate, higher operations and maintenance expense, higher interest expense, and higher depreciation expense. The earnings decrease was partially offset by higher earnings from its capital tracking mechanism due to increased electric system improvements.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Market Risk Information
Commodity Price Risk Management: Our regulated companies enter into energy contracts to serve our customers, and the economic impacts of those contracts are passed on to our customers. Accordingly, the regulated companies have no exposure to loss of future earnings or fair values due to these market risk-sensitive instruments. Eversource's Energy Supply Risk Committee, comprised of senior officers, reviews and approves all large-scale energy related transactions entered into by its regulated companies.
Other Risk Management Activities
Interest Rate Risk Management: We manage our interest rate risk exposure in accordance with our written policies and procedures by maintaining a mix of fixed and variable rate long-term debt.
Credit Risk Management: Credit risk relates to the risk of loss that we would incur as a result of non-performance by counterparties pursuant to the terms of our contractual obligations. We serve a wide variety of customers and transact with suppliers that include IPPs, industrial companies, natural gas and electric utilities, oil and natural gas producers, financial institutions, and other energy marketers. Margin accounts exist within this diverse group, and we realize interest receipts and payments related to balances outstanding in these margin accounts. This wide customer and supplier mix generates a need for a variety of contractual structures, products and terms that, in turn, require us to manage the portfolio of market risk inherent in those transactions in a manner consistent with the parameters established by our risk management process.
Our regulated companies are subject to credit risk from certain long-term or high-volume supply contracts with energy marketing companies. Our regulated companies manage the credit risk with these counterparties in accordance with established credit risk practices and monitor contracting risks, including credit risk. As of September 30, 2023, our regulated companies held collateral (letters of credit or cash) of $32.0 million from counterparties related to our standard service contracts. As of September 30, 2023, Eversource had $28.5 million of cash posted with ISO-NE related to energy transactions.
We have provided additional disclosures regarding interest rate risk management and credit risk management in Part II, Item 7A, "Quantitative and Qualitative Disclosures about Market Risk," in Eversource's 2022 Form 10-K, which is incorporated herein by reference. There have been no additional risks identified and no material changes with regard to the items previously disclosed in the Eversource 2022 Form 10-K.
ITEM 4. CONTROLS AND PROCEDURES
Management, on behalf of Eversource, CL&P, NSTAR Electric and PSNH, evaluated the design and operation of the disclosure controls and procedures as of September 30, 2023 to determine whether they are effective in ensuring that the disclosure of required information is made timely and in accordance with the Securities Exchange Act of 1934 and the rules and regulations of the SEC. This evaluation was made under management's supervision and with management's participation, including the principal executive officer and principal financial officer as of the end of the period covered by this Quarterly Report on Form 10-Q. There are inherent limitations of disclosure controls and procedures, including the possibility of human error and the circumventing or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives. The principal executive officer and principal financial officer have concluded, based on their review, that the disclosure controls and procedures of Eversource, CL&P, NSTAR Electric and PSNH are effective to ensure that information required to be disclosed by us in reports filed under the Securities Exchange Act of 1934 (i) is recorded, processed, summarized, and reported within the time periods specified in SEC rules and regulations and (ii) is accumulated and communicated to management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosures.
There have been no changes in internal controls over financial reporting for Eversource, CL&P, NSTAR Electric and PSNH during the quarter ended September 30, 2023 that have materially affected, or are reasonably likely to materially affect, internal controls over financial reporting.
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PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
We are parties to various legal proceedings. We have disclosed certain legal proceedings in Part I, Item 3, "Legal Proceedings," and elsewhere in our 2022 Form 10-K. These disclosures are incorporated herein by reference. There have been no material legal proceedings identified and no material changes with regard to the legal proceedings previously disclosed in our 2022 Form 10-K.
ITEM 1A. RISK FACTORS
We are subject to a variety of significant risks in addition to the matters set forth under our forward-looking statements section in Item 2, "Management's Discussion and Analysis of Financial Condition and Results of Operations," of this Quarterly Report on Form 10-Q. We have identified a number of these risk factors in Part I, Item 1A, "Risk Factors," in our 2022 Form 10-K, which risk factors are incorporated herein by reference. These risk factors should be considered carefully in evaluating our risk profile. There have been no additional risk factors identified and no material changes with regard to the risk factors previously disclosed in our 2022 Form 10-K.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
The following table discloses purchases of our common shares made by us or on our behalf for the periods shown below. The common shares purchased consist of open market purchases made by the Company or an independent agent. These share transactions related to matching contributions under the Eversource 401k Plan.

Period | Total Number of Shares Purchased | Average Price Paid per Share | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs | Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans and Programs (at month end)
July 1 - July 31, 2023 | — |  | $ | — |  | — |  | — |
August 1 - August 31, 2023 | — |  | — |  | — |  | — |
September 1 - September 30, 2023 | 3,239 |  | 58.52 |  | — |  | — |
Total | 3,239 |  | $ | 58.52 |  | — |  | — |

ITEM 3. DEFAULTS UPON SENIOR SECURITIES
Not applicable.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
ITEM 5. OTHER INFORMATION
During the quarter ended September 30, 2023, 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 Chief Executive Officer of Eversource Energy pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
| 31.1 | Certification by the Chief Financial Officer of Eversource Energy pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
| 32 | Certification by the Chief Executive Officer and Chief Financial Officer of Eversource Energy pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
| Listing of Exhibits (CL&P)
| 31 | Certification by the 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 5.60% Debenture due October 1, 2028 (Exhibit 4.1, NSTAR Electric Company Current Report on Form 8-K filed on September 25, 2023, 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)
* | 4 | Twenty-Sixth Supplemental Indenture, between PSNH and U.S. Bank Trust Company, National Association, as Trustee dated as of September 1, 2023 (Exhibit 4.1, PSNH Current Report on Form 8-K filed on September 25, 2023 (File No. 001-06392)
| 31 | Certification by the Chairman of Public Service Company of New Hampshire pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
| 31.1 | Certification by the Chief Financial Officer of Public Service Company of New Hampshire pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
| 32 | Certification by the Chairman and the Chief Financial Officer of Public Service Company of New Hampshire pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
| Listing of Exhibits (Eversource, CL&P, NSTAR Electric, PSNH)
| 101.INS | Inline XBRL Instance Document - the instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document
| 101.SCH | Inline XBRL Taxonomy Extension Schema
| 101.CAL | Inline XBRL Taxonomy Extension Calculation
| 101.DEF | Inline XBRL Taxonomy Extension Definition
| 101.LAB | Inline XBRL Taxonomy Extension Labels
| 101.PRE | Inline XBRL Taxonomy Extension Presentation
| 104 | The cover page from the Quarterly Report on Form 10-Q for the quarter ended September 30, 2023, 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
November 7, 2023 |  | By: | /s/ Jay S. Buth
|  |  | Jay S. Buth
|  |  | Vice President, Controller and Chief Accounting Officer

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

|  | THE CONNECTICUT LIGHT AND POWER COMPANY
November 7, 2023 |  | By: | /s/ Jay S. Buth
|  |  | Jay S. Buth
|  |  | Vice President, Controller and Chief Accounting Officer

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

|  | NSTAR ELECTRIC COMPANY
November 7, 2023 |  | By: | /s/ Jay S. Buth
|  |  | Jay S. Buth
|  |  | Vice President, Controller and Chief Accounting Officer

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

|  | PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE
November 7, 2023 |  | By: | /s/ Jay S. Buth
|  |  | Jay S. Buth
|  |  | Vice President, Controller and Chief Accounting Officer

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