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Eversource Energy and Subsidiaries 42 The Connecticut Light and Power Company, NSTAR Electric Company and Subsidiary, and Public Service Company of New Hampshire and Subsidiaries 61 ITEM 3. Quantitative and Qualitative Disclosures About Market Risk 66 ITEM 4. Controls and Procedures 66 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 67 ITEM 3. Defaults Upon Senior Securities 67 ITEM 4. Mine Safety Disclosures 67 ITEM 5. Other Information 67 ITEM 6. Exhibits 68 SIGNATURES 70 iii EVERSOURCE ENERGY AND SUBSIDIARIES CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Thousands of Dollars) As of June 30, 2026 As of December 31, 2025 ASSETS Current Assets: Cash and Cash Equivalents $ 1,819,319 $ 135,351 Receivables, Net (net of allowance for uncollectible accounts of $644,889 and $580,539 as of June 30, 2026 and December 31, 2025, respectively) 1,723,357 1,847,094 Unbilled Revenues 182,796 275,108 Materials, Supplies, Natural Gas and REC Inventory 467,200 491,592 Regulatory Assets 1,905,179 1,975,083 Prepayments and Other Current Assets 344,480 352,958 Total Current Assets 6,442,331 5,077,186 Property, Plant and Equipment, Net 45,270,581 45,930,959 Deferred Debits and Other Assets: Regulatory Assets 5,241,018 5,718,646 Goodwill 3,571,333 4,233,767 Prepaid Pension and PBOP 1,550,884 1,511,169 Marketable Securities 319,985 317,101 Other Long-Term Assets 1,019,611 997,883 Total Deferred Debits and Other Assets 11,702,831 12,778,566 Total Assets $ 63,415,743 $ 63,786,711 LIABILITIES AND CAPITALIZATION Current Liabilities: Notes Payable $ 393,700 $ 1,525,445 Long-Term Debt – Current Portion 2,502,629 1,392,948 Rate Reduction Bonds – Current Portion 43,210 43,210 Accounts Payable 1,605,121 1,859,692 Accrued Interest 403,091 380,231 Regulatory Liabilities 1,696,398 1,264,609 Offshore Wind Contingent Liability 409,157 448,158 Other Current Liabilities 1,001,529 894,219 Total Current Liabilities 8,054,835 7,808,512 Deferred Credits and Other Liabilities: Accumulated Deferred Income Taxes 5,732,055 5,647,218 Regulatory Liabilities 4,231,128 4,273,465 Derivative Liabilities 390,341 753,149 Asset Retirement Obligations 605,690 595,442 Accrued SERP and PBOP 99,098 100,859 Other Long-Term Liabilities 938,604 1,101,932 Total Deferred Credits and Other Liabilities 11,996,916 12,472,065 Long-Term Debt 26,608,990 26,872,433 Rate Reduction Bonds 259,257 280,862 Noncontrolling Interest – Preferred Stock of Subsidiaries 155,568 155,568 Common Shareholders' Equity: Common Shares 1,915,718 1,914,273 Capital Surplus, Paid In 9,993,108 9,937,878 Retained Earnings 4,573,332 4,504,983 Accumulated Other Comprehensive Loss (19,346) (20,507) Treasury Stock (122,635) (139,356) Common Shareholders' Equity 16,340,177 16,197,271 Commitments and Contingencies (Note 9) Total Liabilities and Capitalization $ 63,415,743 $ 63,786,711 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 1 EVERSOURCE ENERGY AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) For the Three Months Ended June 30, For the Six Months Ended June 30, (Thousands of Dollars, Except Share Information) 2026 2025 2026 2025 Operating Revenues $ 2,903,189 $ 2,838,068 $ 7,407,552 $ 6,956,423 Operating Expenses: Purchased Power, Purchased Natural Gas and Transmission 939,514 818,747 2,457,688 2,159,084 Operations and Maintenance 480,441 467,557 987,420 955,008 Depreciation 423,914 385,595 844,396 765,175 Amortization (44,323) 109,103 358,441 564,552 Energy Efficiency Programs 173,231 135,290 464,730 392,840 Taxes Other Than Income Taxes 278,178 258,727 566,495 530,321 Sale of Aquarion 111,360 — 111,360 — Total Operating Expenses 2,362,315 2,175,019 5,790,530 5,366,980 Operating Income 540,874 663,049 1,617,022 1,589,443 Interest Expense 355,490 293,193 720,749 594,042 Loss on Offshore Wind 194,000 — 194,000 — Other Income, Net 144,033 95,363 245,192 187,706 Income Before Income Tax Expense 135,417 465,219 947,465 1,183,107 Income Tax Expense 79,857 110,611 283,184 275,831 Net Income 55,560 354,608 664,281 907,276 Net Income Attributable to Noncontrolling Interests 1,880 1,880 3,759 3,759 Net Income Attributable to Common Shareholders $ 53,680 $ 352,728 $ 660,522 $ 903,517 Basic Earnings Per Common Share $ 0.14 $ 0.96 $ 1.76 $ 2.46 Diluted Earnings Per Common Share $ 0.14 $ 0.96 $ 1.75 $ 2.45 Weighted Average Common Shares Outstanding: Basic 376,488,004 368,661,995 376,257,047 367,991,121 Diluted 376,998,879 368,917,187 376,791,247 368,297,404 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) For the Three Months Ended June 30, For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 2026 2025 Net Income $ 55,560 $ 354,608 $ 664,281 $ 907,276 Other Comprehensive Income, Net of Tax: Qualified Cash Flow Hedging Instruments 5 5 10 10 Changes in Funded Status of Pension, SERP and PBOP Benefit Plans 1,026 32 1,151 2,550 Other Comprehensive Income, Net of Tax 1,031 37 1,161 2,560 Comprehensive Income Attributable to Noncontrolling Interests (1,880) (1,880) (3,759) (3,759) Comprehensive Income Attributable to Common Shareholders $ 54,711 $ 352,765 $ 661,683 $ 906,077 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 2 EVERSOURCE ENERGY AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (Unaudited) For the Six Months Ended June 30, 2026 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, 2026 375,416,880 $ 1,914,273 $ 9,937,878 $ 4,504,983 $ (20,507) $ (139,356) $ 16,197,271 Net Income 608,721 608,721 Dividends on Common Shares - $0.7875 Per Share (295,978) (295,978) Dividends on Preferred Stock (1,880) (1,880) Long-Term Incentive Plan Activity (24,577) (24,577) Issuance of Treasury Shares 557,764 36,812 10,451 47,263 Other Comprehensive Income 130 130 Balance as of March 31, 2026 375,974,644 1,914,273 9,950,113 4,815,846 (20,377) (128,905) 16,530,950 Net Income 55,560 55,560 Dividends on Common Shares - $0.7875 Per Share (296,194) (296,194) Dividends on Preferred Stock (1,880) (1,880) Issuance of Common Shares - $5 par value 289,044 1,445 19,102 20,547 Capital Stock Expense (342) (342) Long-Term Incentive Plan Activity 6,960 6,960 Issuance of Treasury Shares 334,649 17,275 6,270 23,545 Other Comprehensive Income 1,031 1,031 Balance as of June 30, 2026 376,598,337 $ 1,915,718 $ 9,993,108 $ 4,573,332 $ (19,346) $ (122,635) $ 16,340,177 For the Six Months Ended June 30, 2025 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, 2025 366,608,052 $ 1,878,622 $ 9,428,905 $ 3,929,141 $ (26,472) $ (170,809) $ 15,039,387 Net Income 552,668 552,668 Dividends on Common Shares - $0.7525 Per Share (276,229) (276,229) Dividends on Preferred Stock (1,880) (1,880) Long-Term Incentive Plan Activity (28,230) (28,230) Issuance of Treasury Shares 699,031 39,921 13,097 53,018 Other Comprehensive Income 2,523 2,523 Balance as of March 31, 2025 367,307,083 1,878,622 9,440,596 4,203,700 (23,949) (157,712) 15,341,257 Net Income 354,608 354,608 Dividends on Common Shares - $0.7525 Per Share (276,513) (276,513) Dividends on Preferred Stock (1,880) (1,880) Issuance of Common Shares - $5 par value 3,378,765 16,894 203,895 220,789 Capital Stock Expense (2,768) (2,768) Long-Term Incentive Plan Activity 8,344 8,344 Issuance of Treasury Shares 352,763 15,307 6,610 21,917 Other Comprehensive Income 37 37 Balance as of June 30, 2025 371,038,611 $ 1,895,516 $ 9,665,374 $ 4,279,915 $ (23,912) $ (151,102) $ 15,665,791 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 3 EVERSOURCE ENERGY AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 Operating Activities: Net Income $ 664,281 $ 907,276 Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: Depreciation 844,396 765,175 Deferred Income Taxes 78,473 10,937 Uncollectible Expense 50,585 41,519 Pension, SERP and PBOP Income, Net (54,253) (39,373) Regulatory Over Recoveries, Net 210,184 28,133 Amortization 358,441 564,552 Cost of Removal Expenditures (102,024) (161,020) Sale of Aquarion 111,360 — Loss on Offshore Wind 194,000 — Other 180,360 24,873 Changes in Current Assets and Liabilities: Receivables and Unbilled Revenues, Net 71,340 (51,220) Taxes Receivable/Accrued, Net 122,183 323,484 Accounts Payable (224,254) (156,507) Other Current Assets and Liabilities, Net (90,289) (159,925) Net Cash Flows Provided by Operating Activities 2,414,783 2,097,904 Investing Activities: Investments in Property, Plant and Equipment (2,023,472) (2,049,401) Proceeds from Sales of Marketable Securities 126,090 123,899 Purchases of Marketable Securities (121,375) (116,775) Payments for Offshore Wind Contingent Liability (233,001) (68,632) Proceeds from Sale of Aquarion 2,334,136 — Other Investing Activities 23,090 7,722 Net Cash Flows Provided by/(Used in) Investing Activities 105,468 (2,103,187) Financing Activities: Issuance of Common Shares, Net of Issuance Costs 20,205 218,021 Cash Dividends on Common Shares (580,281) (540,859) Cash Dividends on Preferred Stock (3,759) (3,759) Decrease in Notes Payable (1,030,445) (662,293) Repayment of Rate Reduction Bonds (21,605) (21,605) Issuance of Long-Term Debt 2,404,894 1,728,193 Retirement of Long-Term Debt (1,616,803) (375,122) Other Financing Activities (44,651) (26,815) Net Cash Flows (Used in)/Provided by Financing Activities (872,445) 315,761 Net Increase in Cash, Cash Equivalents and Restricted Cash 1,647,806 310,478 Cash, Cash Equivalents and Restricted Cash - Beginning of Period 246,245 127,308 Cash, Cash Equivalents and Restricted Cash - End of Period $ 1,894,051 $ 437,786 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 4 THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED BALANCE SHEETS (Unaudited) (Thousands of Dollars) As of June 30, 2026 As of December 31, 2025 ASSETS Current Assets: Cash $ 528 $ 87,615 Receivables, Net (net of allowance for uncollectible accounts of $274,970 and $258,514 as of June 30, 2026 and December 31, 2025, respectively) 642,854 652,150 Accounts Receivable from Affiliated Companies 31,307 60,995 Unbilled Revenues 55,836 63,508 Materials and Supplies 140,378 133,908 Regulatory Assets 254,519 265,175 Prepayments and Other Current Assets 53,962 50,579 Total Current Assets 1,179,384 1,313,930 Property, Plant and Equipment, Net 13,954,692 13,623,296 Deferred Debits and Other Assets: Regulatory Assets 1,736,547 1,716,212 Prepaid Pension and PBOP 208,500 204,067 Other Long-Term Assets 300,028 321,234 Total Deferred Debits and Other Assets 2,245,075 2,241,513 Total Assets $ 17,379,151 $ 17,178,739 LIABILITIES AND CAPITALIZATION Current Liabilities: Notes Payable to Eversource Parent $ 107,000 $ — Long-Term Debt – Current Portion 500,000 — Accounts Payable 534,591 637,467 Accounts Payable to Affiliated Companies 98,922 141,610 Accrued Taxes 38,912 165,362 Regulatory Liabilities 653,665 417,498 Other Current Liabilities 199,497 220,592 Total Current Liabilities 2,132,587 1,582,529 Deferred Credits and Other Liabilities: Accumulated Deferred Income Taxes 1,994,848 2,005,888 Regulatory Liabilities 1,479,698 1,445,140 Other Long-Term Liabilities 274,934 239,289 Total Deferred Credits and Other Liabilities 3,749,480 3,690,317 Long-Term Debt 4,611,306 5,110,067 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 3,684,265 3,684,265 Retained Earnings 3,024,842 2,934,877 Accumulated Other Comprehensive Income 119 132 Common Stockholder's Equity 6,769,578 6,679,626 Commitments and Contingencies (Note 9) Total Liabilities and Capitalization $ 17,379,151 $ 17,178,739 The accompanying notes are an integral part of these unaudited condensed financial statements. 5 THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED STATEMENTS OF INCOME (Unaudited) For the Three Months Ended June 30, For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 2026 2025 Operating Revenues $ 1,049,624 $ 1,132,168 $ 2,617,750 $ 2,673,357 Operating Expenses: Purchased Power and Transmission 460,925 380,280 1,049,071 874,484 Operations and Maintenance 193,816 201,754 384,159 390,910 Depreciation 113,030 107,716 224,775 214,396 Amortization of Regulatory (Liabilities)/Assets, Net (77,928) 74,820 202,095 418,033 Energy Efficiency Programs 31,769 40,042 68,007 91,653 Taxes Other Than Income Taxes 109,598 105,766 230,163 221,027 Total Operating Expenses 831,210 910,378 2,158,270 2,210,503 Operating Income 218,414 221,790 459,480 462,854 Interest Expense 64,150 47,706 138,337 97,616 Other Income, Net 17,216 12,498 34,831 30,096 Income Before Income Tax Expense 171,480 186,582 355,974 395,334 Income Tax Expense 41,264 47,941 86,429 100,457 Net Income $ 130,216 $ 138,641 $ 269,545 $ 294,877 The accompanying notes are an integral part of these unaudited condensed financial statements. CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) For the Three Months Ended June 30, For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 2026 2025 Net Income $ 130,216 $ 138,641 $ 269,545 $ 294,877 Other Comprehensive Loss, Net of Tax: Qualified Cash Flow Hedging Instruments (6) (7) (13) (13) Other Comprehensive Loss, Net of Tax (6) (7) (13) (13) Comprehensive Income $ 130,210 $ 138,634 $ 269,532 $ 294,864 The accompanying notes are an integral part of these unaudited condensed financial statements. 6 THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (Unaudited) For the Six Months Ended June 30, 2026 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, 2026 6,035,205 $ 60,352 $ 3,684,265 $ 2,934,877 $ 132 $ 6,679,626 Net Income 139,329 139,329 Dividends on Preferred Stock (1,390) (1,390) Dividends on Common Stock (88,400) (88,400) Other Comprehensive Loss (7) (7) Balance as of March 31, 2026 6,035,205 60,352 3,684,265 2,984,416 125 6,729,158 Net Income 130,216 130,216 Dividends on Preferred Stock (1,390) (1,390) Dividends on Common Stock (88,400) (88,400) Other Comprehensive Loss (6) (6) Balance as of June 30, 2026 6,035,205 $ 60,352 $ 3,684,265 $ 3,024,842 $ 119 $ 6,769,578 For the Six Months Ended June 30, 2025 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, 2025 6,035,205 $ 60,352 $ 3,684,265 $ 2,819,107 $ 158 $ 6,563,882 Net Income 156,236 156,236 Dividends on Preferred Stock (1,390) (1,390) Dividends on Common Stock (247,000) (247,000) Other Comprehensive Loss (6) (6) Balance as of March 31, 2025 6,035,205 60,352 3,684,265 2,726,953 152 6,471,722 Net Income 138,641 138,641 Dividends on Preferred Stock (1,390) (1,390) Dividends on Common Stock (83,000) (83,000) Other Comprehensive Loss (7) (7) Balance as of June 30, 2025 6,035,205 $ 60,352 $ 3,684,265 $ 2,781,204 $ 145 $ 6,525,966 The accompanying notes are an integral part of these unaudited condensed financial statements. 7 THE CONNECTICUT LIGHT AND POWER COMPANY CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 Operating Activities: Net Income $ 269,545 $ 294,877 Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: Depreciation 224,775 214,396 Deferred Income Taxes (27,425) (34,392) Uncollectible Expense 9,842 10,118 Pension, SERP, and PBOP Income, Net (9,214) (7,079) Regulatory Over/(Under) Recoveries, Net 67,550 (101,300) Amortization of Regulatory Assets, Net 202,095 418,033 Cost of Removal Expenditures (28,013) (33,705) Other 10,711 8,996 Changes in Current Assets and Liabilities: Receivables and Unbilled Revenues, Net 10,050 (626) Taxes Receivable/Accrued, Net (159,800) 56,582 Accounts Payable (119,101) (97,388) Other Current Assets and Liabilities, Net 46,894 25,100 Net Cash Flows Provided by Operating Activities 497,909 753,612 Investing Activities: Investments in Property, Plant and Equipment (511,487) (438,153) Net Cash Flows Used in Investing Activities (511,487) (438,153) Financing Activities: Cash Dividends on Common Stock (176,800) (330,000) Cash Dividends on Preferred Stock (2,779) (2,779) Issuance of Long-Term Debt — 400,000 Increase/(Decrease) in Notes Payable to Eversource Parent 107,000 (280,000) Other Financing Activities (911) (4,520) Net Cash Flows Used in Financing Activities (73,490) (217,299) Net (Decrease)/Increase in Cash and Restricted Cash (87,068) 98,160 Cash and Restricted Cash - Beginning of Period 88,676 2,109 Cash and Restricted Cash - End of Period $ 1,608 $ 100,269 The accompanying notes are an integral part of these unaudited condensed financial statements. 8 NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Thousands of Dollars) As of June 30, 2026 As of December 31, 2025 ASSETS Current Assets: Cash $ 15,356 $ 8,302 Receivables, Net (net of allowance for uncollectible accounts of $141,099 and $132,561 as of June 30, 2026 and December 31, 2025, respectively) 591,679 616,280 Accounts Receivable from Affiliated Companies 134,956 280,099 Unbilled Revenues 55,520 56,948 Materials, Supplies and REC Inventory 185,871 210,865 Regulatory Assets 1,056,092 978,754 Derivative Assets 115,114 91,011 Prepayments and Other Current Assets 26,550 90,040 Total Current Assets 2,181,138 2,332,299 Property, Plant and Equipment, Net 15,911,988 15,308,896 Deferred Debits and Other Assets: Regulatory Assets 1,543,297 1,823,522 Prepaid Pension and PBOP 832,749 804,109 Other Long-Term Assets 288,315 264,073 Total Deferred Debits and Other Assets 2,664,361 2,891,704 Total Assets $ 20,757,487 $ 20,532,899 LIABILITIES AND CAPITALIZATION Current Liabilities: Notes Payable $ 63,000 $ 245,445 Long-Term Debt – Current Portion 700,000 300,000 Accounts Payable 566,975 558,227 Accounts Payable to Affiliated Companies 126,697 198,085 Obligations to Third-Party Suppliers 164,749 179,757 Regulatory Liabilities 775,303 650,813 Other Current Liabilities 175,456 208,979 Total Current Liabilities 2,572,180 2,341,306 Deferred Credits and Other Liabilities: Accumulated Deferred Income Taxes 2,158,686 2,087,287 Regulatory Liabilities 1,728,295 1,702,059 Derivative Liabilities 390,341 753,149 Other Long-Term Liabilities 418,630 401,625 Total Deferred Credits and Other Liabilities 4,695,952 4,944,120 Long-Term Debt 5,641,846 5,645,638 Preferred Stock Not Subject to Mandatory Redemption 43,000 43,000 Common Stockholder's Equity: Common Stock — — Capital Surplus, Paid In 4,496,842 4,238,842 Retained Earnings 3,307,495 3,319,768 Accumulated Other Comprehensive Income 172 225 Common Stockholder's Equity 7,804,509 7,558,835 Commitments and Contingencies (Note 9) Total Liabilities and Capitalization $ 20,757,487 $ 20,532,899 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 9 NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) For the Three Months Ended June 30, For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 2026 2025 Operating Revenues $ 937,889 $ 868,925 $ 2,068,977 $ 1,883,152 Operating Expenses: Purchased Power and Transmission 227,137 225,716 537,295 534,662 Operations and Maintenance 190,038 168,365 386,708 342,503 Depreciation 119,969 109,331 239,306 217,346 Amortization of Regulatory Assets, Net 15,263 15,435 89,979 67,719 Energy Efficiency Programs 85,009 44,258 193,262 107,697 Taxes Other Than Income Taxes 83,912 76,187 159,621 152,024 Total Operating Expenses 721,328 639,292 1,606,171 1,421,951 Operating Income 216,561 229,633 462,806 461,201 Interest Expense 72,436 55,407 152,712 114,627 Other Income, Net 54,098 47,715 105,783 94,009 Income Before Income Tax Expense 198,223 221,941 415,877 440,583 Income Tax Expense 44,466 53,012 96,170 104,479 Net Income $ 153,757 $ 168,929 $ 319,707 $ 336,104 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) For the Three Months Ended June 30, For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 2026 2025 Net Income $ 153,757 $ 168,929 $ 319,707 $ 336,104 Other Comprehensive Loss, Net of Tax: Changes in Funded Status of SERP Benefit Plan (31) (5) (63) (12) Qualified Cash Flow Hedging Instruments 5 5 10 10 Other Comprehensive Loss, Net of Tax (26) — (53) (2) Comprehensive Income $ 153,731 $ 168,929 $ 319,654 $ 336,102 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 10 NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (Unaudited) For the Six Months Ended June 30, 2026 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, 2026 200 $ — $ 4,238,842 $ 3,319,768 $ 225 $ 7,558,835 Net Income 165,950 165,950 Dividends on Preferred Stock (490) (490) Capital Contributions from Eversource Parent 258,000 258,000 Other Comprehensive Loss (27) (27) Balance as of March 31, 2026 200 — 4,496,842 3,485,228 198 7,982,268 Net Income 153,757 153,757 Dividends on Preferred Stock (490) (490) Dividends on Common Stock (331,000) (331,000) Other Comprehensive Loss (26) (26) Balance as of June 30, 2026 200 $ — $ 4,496,842 $ 3,307,495 $ 172 $ 7,804,509 For the Six Months Ended June 30, 2025 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, 2025 200 $ — $ 3,788,842 $ 3,127,105 $ (141) $ 6,915,806 Net Income 167,175 167,175 Dividends on Preferred Stock (490) (490) Dividends on Common Stock (436,000) (436,000) Capital Contributions from Eversource Parent 100,000 100,000 Other Comprehensive Loss (2) (2) Balance as of March 31, 2025 200 — 3,888,842 2,857,790 (143) 6,746,489 Net Income 168,929 168,929 Dividends on Preferred Stock (490) (490) Balance as of June 30, 2025 200 $ — $ 3,888,842 $ 3,026,229 $ (143) $ 6,914,928 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 11 NSTAR ELECTRIC COMPANY AND SUBSIDIARY CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 Operating Activities: Net Income $ 319,707 $ 336,104 Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: Depreciation 239,306 217,346 Deferred Income Taxes 48,544 21,446 Uncollectible Expense 15,604 14,002 Pension, SERP and PBOP Income, Net (22,439) (19,942) Regulatory (Under)/Over Recoveries, Net (32,099) 52,121 Amortization of Regulatory Assets, Net 89,979 67,719 Cost of Removal Expenditures (24,095) (49,103) Other (32,994) (3,324) Changes in Current Assets and Liabilities: Receivables and Unbilled Revenues, Net 158,212 (107,269) Taxes Receivable/Accrued, Net 52,335 1,038 Accounts Payable (127,987) (55,534) Other Current Assets and Liabilities, Net (57,945) (80,994) Net Cash Flows Provided by Operating Activities 626,128 393,610 Investing Activities: Investments in Property, Plant and Equipment (773,806) (775,162) Net Cash Flows Used in Investing Activities (773,806) (775,162) Financing Activities: Cash Dividends on Common Stock (331,000) (436,000) Cash Dividends on Preferred Stock (980) (980) Issuance of Long-Term Debt 700,000 800,000 Retirement of Long-Term Debt (300,000) — Capital Contributions from Eversource Parent 258,000 100,000 Decrease in Notes Payable (182,445) (74,782) Other Financing Activities (5,230) (9,110) Net Cash Flows Provided by Financing Activities 138,345 379,128 Net Decrease in Cash and Restricted Cash (9,333) (2,424) Cash and Restricted Cash - Beginning of Period 25,944 9,023 Cash and Restricted Cash - End of Period $ 16,611 $ 6,599 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 12 PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Thousands of Dollars) As of June 30, 2026 As of December 31, 2025 ASSETS Current Assets: Cash and Cash Equivalents $ 56,074 $ 13,665 Receivables, Net (net of allowance for uncollectible accounts of $24,931 and $23,547 as of June 30, 2026 and December 31, 2025, respectively) 219,539 214,117 Accounts Receivable from Affiliated Companies 21,168 24,338 Unbilled Revenues 55,002 62,446 Materials, Supplies and REC Inventory 78,682 58,879 Regulatory Assets 142,236 119,871 Special Deposits 34,418 38,343 Prepayments and Other Current Assets 28,803 19,212 Total Current Assets 635,922 550,871 Property, Plant and Equipment, Net 5,632,513 5,507,663 Deferred Debits and Other Assets: Regulatory Assets 821,386 841,203 Prepaid Pension and PBOP 118,512 111,833 Other Long-Term Assets 25,847 17,661 Total Deferred Debits and Other Assets 965,745 970,697 Total Assets $ 7,234,180 $ 7,029,231 LIABILITIES AND CAPITALIZATION Current Liabilities: Notes Payable to Eversource Parent $ 2,100 $ 49,300 Rate Reduction Bonds – Current Portion 43,210 43,210 Accounts Payable 166,674 179,137 Accounts Payable to Affiliated Companies 31,781 45,277 Obligations to Third-Party Suppliers 36,624 37,584 Renewable Portfolio Standards Compliance Obligations 33,288 20,730 Accrued Interest 37,061 35,224 Regulatory Liabilities 150,745 118,443 Other Current Liabilities 32,627 41,604 Total Current Liabilities 534,110 570,509 Deferred Credits and Other Liabilities: Accumulated Deferred Income Taxes 824,718 806,270 Regulatory Liabilities 432,400 417,442 Other Long-Term Liabilities 49,185 46,669 Total Deferred Credits and Other Liabilities 1,306,303 1,270,381 Long-Term Debt 2,234,486 2,031,323 Rate Reduction Bonds 259,257 280,862 Common Stockholder's Equity: Common Stock — — Capital Surplus, Paid In 1,973,134 1,973,134 Retained Earnings 926,890 903,022 Common Stockholder's Equity 2,900,024 2,876,156 Commitments and Contingencies (Note 9) Total Liabilities and Capitalization $ 7,234,180 $ 7,029,231 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 13 PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) For the Three Months Ended June 30, For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 2026 2025 Operating Revenues $ 333,940 $ 303,133 $ 717,457 $ 651,114 Operating Expenses: Purchased Power and Transmission 65,704 39,269 154,899 119,276 Operations and Maintenance 67,288 66,995 128,827 138,005 Depreciation 44,972 41,269 89,411 81,771 Amortization of Regulatory Assets, Net 8,249 26,829 34,899 47,665 Energy Efficiency Programs 7,824 10,542 18,313 22,745 Taxes Other Than Income Taxes 28,443 27,213 55,729 52,998 Total Operating Expenses 222,480 212,117 482,078 462,460 Operating Income 111,460 91,016 235,379 188,654 Interest Expense 26,699 20,503 55,316 41,073 Other Income, Net 10,358 13,725 20,861 24,484 Income Before Income Tax Expense 95,119 84,238 200,924 172,065 Income Tax Expense 23,128 20,323 49,156 41,871 Net Income $ 71,991 $ 63,915 $ 151,768 $ 130,194 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 14 PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (Unaudited) For the Six Months Ended June 30, 2026 Common Stock Capital Surplus, Paid In Retained Earnings Total Common Stockholder's Equity (Thousands of Dollars, Except Stock Information) Stock Amount Balance as of January 1, 2026 301 $ — $ 1,973,134 $ 903,022 $ 2,876,156 Net Income 79,777 79,777 Dividends on Common Stock (38,900) (38,900) Balance as of March 31, 2026 301 — 1,973,134 943,899 2,917,033 Net Income 71,991 71,991 Dividends on Common Stock (89,000) (89,000) Balance as of June 30, 2026 301 $ — $ 1,973,134 $ 926,890 $ 2,900,024 For the Six Months Ended June 30, 2025 Common Stock Capital Surplus, Paid In Retained Earnings Total Common Stockholder's Equity (Thousands of Dollars, Except Stock Information) Stock Amount Balance as of January 1, 2025 301 $ — $ 1,898,134 $ 808,668 $ 2,706,802 Net Income 66,279 66,279 Capital Contributions from Eversource Parent 75,000 75,000 Balance as of March 31, 2025 301 — 1,973,134 874,947 2,848,081 Net Income 63,915 63,915 Dividends on Common Stock (175,000) (175,000) Balance as of June 30, 2025 301 $ — $ 1,973,134 $ 763,862 $ 2,736,996 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 15 PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) For the Six Months Ended June 30, (Thousands of Dollars) 2026 2025 Operating Activities: Net Income $ 151,768 $ 130,194 Adjustments to Reconcile Net Income to Net Cash Flows Provided by Operating Activities: Depreciation 89,411 81,771 Deferred Income Taxes 14,690 13,943 Uncollectible Expense 2,627 2,447 Pension, SERP and PBOP Income, Net (5,230) (4,444) Regulatory Under Recoveries, Net (5,870) (36,271) Amortization of Regulatory Assets, Net 34,899 47,665 Cost of Removal Expenditures (11,617) (16,545) Other (6,052) (13,837) Changes in Current Assets and Liabilities: Receivables and Unbilled Revenues, Net 1,183 (16,547) Taxes Receivable/Accrued, Net (4,009) (3,076) Accounts Payable (10,963) 6,151 Other Current Assets and Liabilities, Net (19,936) 483 Net Cash Flows Provided by Operating Activities 230,901 191,934 Investing Activities: Investments in Property, Plant and Equipment (197,386) (275,508) Net Cash Flows Used in Investing Activities (197,386) (275,508) Financing Activities: Cash Dividends on Common Stock (127,900) (175,000) Capital Contributions from Eversource Parent — 75,000 Issuance of Long-Term Debt 200,000 300,000 Repayment of Rate Reduction Bonds (21,605) (21,605) Decrease in Notes Payable to Eversource Parent (47,200) (95,800) Other Financing Activities 1,674 (1,627) Net Cash Flows Provided by Financing Activities 4,969 80,968 Net Increase/(Decrease) in Cash, Cash Equivalents and Restricted Cash 38,484 (2,606) Cash, Cash Equivalents and Restricted Cash - Beginning of Period 55,186 37,243 Cash, Cash Equivalents and Restricted Cash - End of Period $ 93,670 $ 34,637 The accompanying notes are an integral part of these unaudited condensed consolidated financial statements. 16 EVERSOURCE ENERGY AND SUBSIDIARIES THE CONNECTICUT LIGHT AND POWER COMPANY NSTAR ELECTRIC COMPANY AND SUBSIDIARY PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES COMBINED NOTES TO CONDENSED FINANCIAL STATEMENTS (Unaudited) Refer to the Glossary of Terms included in this combined Quarterly Report on Form 10-Q for abbreviations and acronyms used throughout the combined notes to the unaudited condensed financial statements. 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES A. Basis of Presentation Eversource Energy is a public utility holding company primarily engaged, through its wholly-owned regulated utility subsidiaries, in the energy delivery business. Eversource Energy's wholly-owned regulated utility subsidiaries consist of CL&P, NSTAR Electric and PSNH (electric utilities), and Yankee Gas, NSTAR Gas and EGMA (natural gas utilities). Eversource provides energy delivery service to approximately 4.4 million electric and natural gas customers through eight 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 2025 Form 10-K, which was filed with the SEC on February 17, 2026. The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The financial statements contain, in the opinion of management, all adjustments (including normal, recurring adjustments) necessary to present fairly Eversource's, CL&P's, NSTAR Electric's and PSNH's financial position as of June 30, 2026 and December 31, 2025, the results of operations, comprehensive income and common shareholders' equity for the three and six months ended June 30, 2026 and 2025, and the cash flows for the six months ended June 30, 2026 and 2025. The results of operations and comprehensive income for the three and six months ended June 30, 2026 and 2025 and the cash flows for the six months ended June 30, 2026 and 2025 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's utility subsidiaries' 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. On June 30, 2026, Eversource completed the sale of Aquarion consistent with all regulatory terms and requirements. The assets and liabilities associated with the sale of the water distribution business were previously reflected in the Water Distribution segment and reporting unit. Management has elected to continue presenting the results of the Aquarion water distribution business as a separate reportable segment for the current periods and comparative prior periods. See Note 16, "Segment Information" and Note 17, "Sale of Aquarion Water Distribution Business," for further information. Certain reclassifications of prior period data were made in the accompanying financial statements to conform to the current period presentation. B. Accounting Standards Accounting Standards Issued but Not Yet Adopted: In September 2025, the Financial Accounting Standards Board issued ASU 2025-06, Intangibles — Goodwill and Other — Internal-Use Software (Subtopic 350-40) - Targeted Improvements to the Accounting for Internal-Use Software, to modernize and clarify the accounting for software costs. The ASU’s provisions change the criteria for capitalization of software development costs by eliminating consideration of “project development stages” and instead requiring consideration of the probability of software project completion for its intended use. The new accounting guidance is effective for interim and annual periods beginning after December 15, 2027, with early adoption permitted. Entities are permitted to apply one of three transition approaches: prospective, modified transition that is based on the status of the project and whether software costs were capitalized before the date of adoption, or retrospective. Eversource is currently reviewing the requirements of ASU 2025-06. 17 In May 2026, the Financial Accounting Standards Board issued ASU 2026-02, Environmental Credits and Environmental Credit Obligations (Topic 818), to establish a comprehensive model for the recognition, measurement, presentation, and disclosure of environmental credits and environmental credit obligations. The new accounting guidance is effective for interim and annual periods beginning after December 15, 2027, with early adoption permitted. Entities should apply the amendments on a retrospective basis through a cumulative-effect adjustment on the opening balance of retained earnings. Eversource is currently reviewing the requirements of ASU 2026-02. C. Allowance for Uncollectible Accounts Receivables, Net on the balance sheets primarily includes trade receivables from retail customers and customers related to wholesale transmission contracts, wholesale market sales, sales of RECs, and property rentals. Receivables, Net also includes customer receivables for the purchase of electricity from a competitive third-party supplier, the current portion of customer energy efficiency loans, property damage receivables and other miscellaneous receivables. There is no material concentration of receivables. Receivables are recorded at amortized cost, net of a credit loss provision (or allowance for uncollectible accounts). The current expected credit loss (CECL) model is applied to receivables for purposes of calculating the allowance for uncollectible accounts. This model is based on expected losses and results in the recognition of estimated expected credit losses, including uncollectible amounts for both billed and unbilled revenues, over the life of the receivable at the time a receivable is recorded. The allowance for uncollectible accounts is determined based upon various judgments and factors, including an aging-based quantitative assessment that applies an estimated uncollectible percentage to each receivable aging category. Factors in determining credit loss include historical collection, write-off experience, analysis of delinquency statistics, and management's assessment of collectability from customers, including current economic conditions, customer payment trends, the impact on customer bills because of energy usage trends and changes in rates, flexible payment plans and financial hardship arrearage management programs offered to customers, reasonable forecasts, and expectations of future collectability and collection efforts. Management continuously assesses the collectability of receivables and adjusts estimates based on actual experience and future expectations based on economic conditions, collection efforts and other factors. Management also monitors the aging analysis of receivables to determine if there are changes in the collections of accounts receivable. Receivable balances are written off against the allowance for uncollectible accounts when the customer accounts are no longer in service and these balances are deemed to be uncollectible. Management concluded that the reserve balance as of June 30, 2026 adequately reflected the collection risk and net realizable value for its receivables. The PURA allows CL&P and Yankee Gas to accelerate the recovery of accounts receivable balances attributable to qualified customers under financial or medical duress (uncollectible hardship accounts receivable) outstanding for greater than 180 days and 90 days, respectively. The DPU allows NSTAR Electric, NSTAR Gas and EGMA to recover in rates amounts associated with certain uncollectible hardship accounts receivable. These uncollectible hardship customer account balances are included in Regulatory Assets or Other Long-Term Assets on the balance sheets. Hardship customers are protected from shut-off in certain circumstances, and historical collection experience has reflected a higher default risk as compared to the rest of the receivable population. Management uses a higher credit risk profile for this pool of trade receivables as compared to non-hardship receivables. The allowance for uncollectible hardship accounts is included in the total uncollectible allowance balance. The total allowance for uncollectible accounts is included in Receivables, Net on the balance sheets. The activity in the allowance for uncollectible accounts by portfolio segment as of June 30th 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 Balance as of April 1, 2026 $ 383.2 $ 228.5 $ 611.7 $ 238.6 $ 35.4 $ 274.0 $ 56.6 $ 70.5 $ 127.1 $ 24.3 Uncollectible Expense — 19.8 19.8 — 4.3 4.3 — 7.3 7.3 1.2 Uncollectible Costs Deferred (1) 36.7 14.5 51.2 9.0 3.1 12.1 8.8 6.6 15.4 2.0 Write-Offs (10.2) (28.7) (38.9) (8.0) (8.7) (16.7) (0.4) (9.4) (9.8) (2.8) Recoveries Collected 0.3 3.0 3.3 0.3 1.0 1.3 — 1.1 1.1 0.2 Sale of Aquarion (2) — (2.2) (2.2) — — — — — — — Balance as of June 30, 2026 $ 410.0 $ 234.9 $ 644.9 $ 239.9 $ 35.1 $ 275.0 $ 65.0 $ 76.1 $ 141.1 $ 24.9 Balance as of January 1, 2026 $ 367.2 $ 213.3 $ 580.5 $ 225.7 $ 32.8 $ 258.5 $ 60.7 $ 71.9 $ 132.6 $ 23.5 Uncollectible Expense — 50.6 50.6 — 9.8 9.8 — 15.6 15.6 2.6 Uncollectible Costs Deferred (1) 64.5 33.3 97.8 31.1 5.9 37.0 5.3 14.0 19.3 4.2 Write-Offs (22.4) (67.2) (89.6) (17.5) (15.6) (33.1) (1.0) (28.0) (29.0) (5.9) Recoveries Collected 0.7 7.1 7.8 0.6 2.2 2.8 — 2.6 2.6 0.5 Sale of Aquarion (2) — (2.2) (2.2) — — — — — — — Balance as of June 30, 2026 $ 410.0 $ 234.9 $ 644.9 $ 239.9 $ 35.1 $ 275.0 $ 65.0 $ 76.1 $ 141.1 $ 24.9 18 Eversource CL&P NSTAR Electric PSNH (Millions of Dollars) Hardship Accounts Retail (Non-Hardship), Wholesale, and Other Total Allowance Hardship Accounts Retail (Non-Hardship), Wholesale, and Other Total Allowance Hardship Accounts Retail (Non-Hardship), Wholesale, and Other Total Allowance Total Allowance Balance as of April 1, 2025 $ 371.5 $ 194.1 $ 565.6 $ 240.3 $ 35.9 $ 276.2 $ 57.8 $ 58.2 $ 116.0 $ 14.3 Uncollectible Expense — 18.6 18.6 — 5.4 5.4 — 6.5 6.5 1.1 Uncollectible Costs Deferred (1) 14.9 11.8 26.7 3.2 2.9 6.1 3.2 5.8 9.0 1.2 Write-Offs (9.6) (29.6) (39.2) (7.3) (8.1) (15.4) (0.7) (12.1) (12.8) (1.8) Recoveries Collected 0.2 3.7 3.9 0.1 1.2 1.3 — 1.5 1.5 0.2 Balance as of June 30, 2025 $ 377.0 $ 198.6 $ 575.6 $ 236.3 $ 37.3 $ 273.6 $ 60.3 $ 59.9 $ 120.2 $ 15.0 Balance as of January 1, 2025 $ 364.6 $ 191.6 $ 556.2 $ 240.7 $ 38.4 $ 279.1 $ 55.2 $ 59.7 $ 114.9 $ 14.1 Uncollectible Expense — 41.5 41.5 — 10.1 10.1 — 14.0 14.0 2.4 Uncollectible Costs Deferred (1) 34.3 25.6 59.9 12.0 4.8 16.8 6.7 11.3 18.0 2.6 Write-Offs (22.2) (67.4) (89.6) (16.6) (18.2) (34.8) (1.6) (28.0) (29.6) (4.5) Recoveries Collected 0.3 7.3 7.6 0.2 2.2 2.4 — 2.9 2.9 0.4 Balance as of June 30, 2025 $ 377.0 $ 198.6 $ 575.6 $ 236.3 $ 37.3 $ 273.6 $ 60.3 $ 59.9 $ 120.2 $ 15.0 (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. (2) On June 30, 2026, Eversource completed the sale of Aquarion. For further information, see Note 17, "Sale of Aquarion Water Distribution Business." D. Fair Value Measurements Fair value measurement guidance is applied to derivative contracts that are not elected or designated as "normal purchases" or "normal sales" (normal) and to marketable securities held in trusts. Fair value measurement guidance is also applied to valuations of the investments used to calculate the funded status of pension and PBOP plans, the nonrecurring fair value measurements of nonfinancial assets such as goodwill, long-lived assets, equity method investments, AROs, and in the valuation of business combinations and asset acquisitions. The fair value measurement guidance was also applied in estimating the fair value of preferred stock, long-term debt and RRBs. Fair Value Hierarchy: In measuring fair value, Eversource uses observable market data when available in order to minimize the use of unobservable inputs. Inputs used in fair value measurements are categorized into three fair value hierarchy levels for disclosure purposes. The entire fair value measurement is categorized based on the lowest level of input that is significant to the fair value measurement. Eversource evaluates the classification of assets and liabilities measured at fair value on a quarterly basis. The levels of the fair value hierarchy are described below: Level 1 - Inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 2 - Inputs are quoted prices for similar instruments in active markets, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations in which all significant inputs are observable. Level 3 - Quoted market prices are not available. Fair value is derived from valuation techniques in which one or more significant inputs or assumptions are unobservable. Where possible, valuation techniques incorporate observable market inputs that can be validated to external sources such as industry exchanges, including prices of energy and energy-related products. Uncategorized - Investments that are measured at net asset value are not categorized within the fair value hierarchy. Determination of Fair Value: The valuation techniques and inputs used in Eversource's fair value measurements are described in Note 4, "Derivative Instruments," Note 5, "Marketable Securities," and Note 10, "Fair Value of Financial Instruments," to the financial statements. 19 E. Other Income, Net The components of Other Income, Net on the statements of income were as follows: For the Three Months Ended June 30, 2026 June 30, 2025 (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 $ 42.3 $ 11.3 $ 18.3 $ 5.1 $ 35.5 $ 9.3 $ 15.4 $ 4.6 AFUDC Equity 30.9 6.8 16.8 2.7 25.6 1.5 14.7 4.5 Equity in Earnings of Unconsolidated Affiliates 5.1 — 0.1 — 4.8 — 0.2 — Investment Loss (3.4) (1.5) (0.1) (0.7) (2.0) (0.9) (0.2) (0.4) Interest Income 32.6 0.6 19.0 3.2 30.8 2.5 17.6 5.0 Other (1) 36.5 — — 0.1 0.7 0.1 — — Total Other Income, Net $ 144.0 $ 17.2 $ 54.1 $ 10.4 $ 95.4 $ 12.5 $ 47.7 $ 13.7 For the Six Months Ended June 30, 2026 June 30, 2025 (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 $ 86.5 $ 23.2 $ 37.3 $ 10.3 $ 68.1 $ 17.6 $ 30.2 $ 8.7 AFUDC Equity 54.8 11.4 32.5 5.0 49.5 5.1 28.8 8.4 Equity in Earnings of Unconsolidated Affiliates 8.9 — 0.2 — 10.8 — 0.4 — Investment (Loss)/Income (3.1) (1.6) 0.3 (0.7) (4.0) (0.8) (2.0) (0.3) Interest Income 61.0 1.8 35.4 6.2 64.8 8.1 36.6 7.7 Other (1) 37.1 — 0.1 0.1 (1.5) 0.1 — — Total Other Income, Net $ 245.2 $ 34.8 $ 105.8 $ 20.9 $ 187.7 $ 30.1 $ 94.0 $ 24.5 (1) In the second quarter of 2026, Eversource completed the sale of an intangible asset. The transaction resulted in proceeds of $36.0 million, which was recognized as a gain on sale within Other Income. The gain is reflected in the Parent and Other Companies segment and the cash proceeds from sale are presented within Other investing activities on the statement of cash flows. F. Other Taxes Eversource's companies that serve customers in Connecticut collect gross receipts taxes levied by the state of Connecticut from their customers. These gross receipts taxes are recorded separately with collections in Operating Revenues and with payments in Taxes Other Than Income Taxes on the statements of income as follows: For the Three Months Ended For the Six Months Ended (Millions of Dollars) June 30, 2026 June 30, 2025 June 30, 2026 June 30, 2025 Eversource $ 52.8 $ 50.7 $ 120.9 $ 114.4 CL&P 45.6 45.6 98.5 98.5 As agents for state and local governments, Eversource's companies that serve customers in Connecticut and Massachusetts collect certain sales taxes that are recorded on a net basis with no impact on the statements of income. G. Supplemental Cash Flow Information Non-cash investing activities include plant additions included in Accounts Payable as follows: (Millions of Dollars) As of June 30, 2026 As of June 30, 2025 Eversource $ 427.3 $ 405.1 CL&P 105.1 73.1 NSTAR Electric 147.8 124.6 PSNH 44.6 67.7 20 The following table reconciles cash and cash equivalents as reported on the balance sheets to the cash, cash equivalents and restricted cash balance as reported on the statements of cash flows: As of June 30, 2026 As of December 31, 2025 (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 $ 1,819.3 $ 0.5 $ 15.4 $ 56.1 $ 135.4 $ 87.6 $ 8.3 $ 13.7 Restricted cash included in: Special Deposits 59.7 1.1 1.2 34.4 93.6 1.1 17.6 38.3 Marketable Securities 11.9 — — — 14.0 — — — Other Long-Term Assets 3.2 — — 3.2 3.2 — — 3.2 Cash, Cash Equivalents and Restricted Cash as reported on the Statements of Cash Flows $ 1,894.1 $ 1.6 $ 16.6 $ 93.7 $ 246.2 $ 88.7 $ 25.9 $ 55.2 Special Deposits represent cash collections related to the PSNH RRB customer charges that are held in trust, required ISO-NE cash deposits, cash held in escrow accounts, and CYAPC and YAEC cash balances. Special Deposits are included in Current Assets on the balance sheets. Restricted cash included in Marketable Securities represents money market funds held in restricted trusts to fund CYAPC and YAEC's spent nuclear fuel storage obligations. As of June 30, 2026, the Cash and Cash Equivalents balance at Eversource was $1.82 billion. This balance includes approximately $1.7 billion of net proceeds received from the June 30, 2026 sale of Aquarion. The Company expects to utilize these proceeds to reduce Eversource parent debt. See Note 17, "Sale of Aquarion Water Distribution Business," for further information. Eversource’s restricted cash also includes an Energy Relief Fund for energy efficiency and clean energy measures in the Merrimack Valley established under the terms of an EGMA 2020 settlement agreement. This restricted cash held in escrow accounts included $7.5 million and $21.4 million recorded as short-term in Special Deposits as of June 30, 2026 and December 31, 2025, respectively. 2. REGULATORY ACCOUNTING Eversource's utility companies are subject to rate regulation that is based on cost recovery and meets the criteria for application of accounting guidance for rate-regulated operations, which considers the effect of regulation on the timing of the recognition of certain revenues and expenses. The regulated companies' financial statements reflect the effects of the rate-making process. The rates charged to the customers of Eversource's regulated companies are designed to collect each company's costs to provide service, including 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. 21 Regulatory Assets: The components of regulatory assets were as follows: As of June 30, 2026 As of December 31, 2025 (Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH Storm Costs, Net $ 2,044.2 $ 996.9 $ 575.9 $ 471.4 $ 1,959.3 $ 991.3 $ 499.6 $ 468.4 Regulatory Tracking Mechanisms 1,516.5 192.7 792.9 112.8 1,573.8 206.5 705.6 93.2 Benefit Costs 1,025.7 185.1 308.3 64.7 992.8 173.7 300.0 61.7 Income Taxes, Net 866.2 551.4 170.9 22.1 1,044.5 546.1 161.5 23.3 Derivative Contracts 390.3 — 390.3 — 753.2 0.1 753.1 — Securitized Stranded Costs 284.5 — — 284.5 306.1 — — 306.1 Cost of Removal 268.5 — 8.0 — 262.5 — 8.1 — Goodwill-related 222.0 — 190.6 — 230.4 — 197.8 — Asset Retirement Obligations 169.2 45.7 87.6 5.6 162.8 44.2 84.6 5.4 Environmental Remediation Costs 134.1 — — — 136.1 — — — EGMA Acquisition and Integration Costs 82.3 — — — 82.3 — — — Other Regulatory Assets 142.7 19.2 74.9 2.5 189.9 19.5 92.0 3.0 Total Regulatory Assets 7,146.2 1,991.0 2,599.4 963.6 7,693.7 1,981.4 2,802.3 961.1 Less: Current Portion 1,905.2 254.5 1,056.1 142.2 1,975.1 265.2 978.8 119.9 Total Long-Term Regulatory Assets $ 5,241.0 $ 1,736.5 $ 1,543.3 $ 821.4 $ 5,718.6 $ 1,716.2 $ 1,823.5 $ 841.2 On June 30, 2026, Eversource completed the sale of Aquarion. Regulatory Assets as of December 31, 2025 included in the table above related to the Water Distribution Business were $234.7 million. For further information, see Note 17, "Sale of Aquarion Water Distribution Business." CL&P Storm Proceeding: On March 28, 2024, PURA established a prudency review proceeding to evaluate costs reported by CL&P for catastrophic storms and pre‑staging events occurring between January 1, 2018 and December 31, 2023. Storm costs requested by CL&P for this six-year period totaled $974.2 million. CL&P additionally requested approval to recover carrying costs calculated at the weighted average cost of capital on the deferred storm costs totaling $397 million. These carrying costs reflect CL&P’s actual financing costs on the unrecovered storm costs from the date the deferred storm costs were incurred through June 1, 2027, the expected date of securitization. These carrying costs have not been deferred on the balance sheet. On July 29, 2026, PURA issued a final decision approving $869.4 million of prudently incurred catastrophic storms and pre‑staging events occurring between January 1, 2018 and December 31, 2023 and postponing review of $63.3 million of storm costs to a future proceeding. PURA did not approve the recovery of carrying costs from the date the deferred storm costs were incurred through the date of the final decision. PURA approved the accrual of carrying costs on the unrecovered, approved storm costs beginning on the date of the final decision through the date of securitization or other recovery authorized in the CL&P distribution rate case proceeding. Total approved storm costs to be considered by PURA for future securitization are $667.9 million, which excludes $101.5 million of costs that were previously collected from customers through base distribution rates and $100 million approved in the April 2026 RAM proceeding to be collected through the CTA rate from May 1, 2026 through April 30, 2027. CL&P is currently evaluating the impact of costs not allowed for recovery in the decision and potential legal courses of action. The impact of the decision will be recorded in the third quarter of 2026. On May 4, 2026, PURA issued a notice of proceeding to consider whether the issuance of rate reduction bonds for the securitization of approved storm costs is in the best interest of rate payers. A timeline in this proceeding has not yet been established. Regulatory Costs in Other Long-Term Assets: Eversource's regulated companies had $276.1 million (including $139.6 million for CL&P, $56.9 million for NSTAR Electric and $5.1 million for PSNH) and $244.2 million (including $127.1 million for CL&P, $51.0 million for NSTAR Electric and $5.4 million for PSNH) of additional regulatory costs not yet specifically approved as of June 30, 2026 and December 31, 2025, respectively, that were included in Other Long-Term Assets on the balance sheets. These amounts will be reclassified to Regulatory Assets upon approval by the applicable regulatory agency. Based on regulatory policies or past precedent on similar costs, management believes it is probable that these costs will ultimately be approved and recovered from customers in rates. As of June 30, 2026 and December 31, 2025, these regulatory costs included $151.6 million (including $70.6 million for CL&P and $39.8 million for NSTAR Electric) and $123.2 million (including $57.0 million for CL&P and $34.0 million for NSTAR Electric), respectively, of deferred uncollectible hardship costs. 22 Regulatory Liabilities: The components of regulatory liabilities were as follows: As of June 30, 2026 As of December 31, 2025 (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 $ 2,343.9 $ 924.0 $ 834.6 $ 314.8 $ 2,423.4 $ 933.3 $ 847.9 $ 319.8 Regulatory Tracking Mechanisms 1,560.0 673.0 615.7 141.3 1,186.6 457.3 535.2 111.2 Cost of Removal 877.8 310.3 504.9 62.6 867.1 275.1 479.4 45.5 Deferred Portion of Non-Service Income Components of Pension, SERP and PBOP 557.8 79.4 276.4 53.2 509.4 72.8 252.5 48.5 AFUDC - Transmission 196.2 78.0 118.2 — 179.4 72.0 107.4 — Derivative Contract 115.1 — 115.1 — 91.0 — 91.0 — Benefit Costs 74.6 10.4 14.4 7.2 80.4 8.8 24.5 6.8 Other Regulatory Liabilities 202.1 58.3 24.3 4.0 200.8 43.3 15.0 4.0 Total Regulatory Liabilities 5,927.5 2,133.4 2,503.6 583.1 5,538.1 1,862.6 2,352.9 535.8 Less: Current Portion 1,696.4 653.7 775.3 150.7 1,264.6 417.5 650.8 118.4 Total Long-Term Regulatory Liabilities $ 4,231.1 $ 1,479.7 $ 1,728.3 $ 432.4 $ 4,273.5 $ 1,445.1 $ 1,702.1 $ 417.4 On June 30, 2026, Eversource completed the sale of Aquarion. Regulatory Liabilities as of December 31, 2025 included in the table above related to the Water Distribution Business were $150.8 million. For further information, see Note 17, "Sale of Aquarion Water Distribution Business." FERC ROE Complaints: As of June 30, 2026, Eversource has a regulatory liability for revenues subject to refund of $62.0 million (pre-tax) as a result of the March 19, 2026 FERC decision in the FERC ROE complaint proceedings, which is reflected within Regulatory Tracking Mechanisms in the table above. The regulatory liability totaled $29.8 million for CL&P, $24.6 million for NSTAR Electric, and $7.6 million for PSNH. The liability recorded reflects the difference between the billed ROE and the replacement ROE for the first complaint period, including interest. Eversource does not have any other reserves recorded for the other complaint periods, as these remaining complaints were dismissed in the decision. See Note 9C, "Commitments and Contingencies – FERC ROE Complaints," for further information on the FERC ROE decision. 3. PROPERTY, PLANT AND EQUIPMENT AND ACCUMULATED DEPRECIATION The following tables summarize property, plant and equipment by asset category: Eversource As of June 30, 2026 As of December 31, 2025 (Millions of Dollars) Distribution - Electric $ 23,536.1 $ 22,695.3 Distribution - Natural Gas 9,980.2 9,888.0 Transmission - Electric 17,283.3 17,082.4 Distribution - Water (1) — 2,577.3 Solar 206.8 206.8 Utility 51,006.4 52,449.8 Other (2) 2,655.4 2,476.3 Property, Plant and Equipment, Gross 53,661.8 54,926.1 Less: Accumulated Depreciation Utility (10,502.9) (10,911.7) Other (1,386.7) (1,246.1) Total Accumulated Depreciation (11,889.6) (12,157.8) Property, Plant and Equipment, Net 41,772.2 42,768.3 Construction Work in Progress 3,498.4 3,162.7 Total Property, Plant and Equipment, Net $ 45,270.6 $ 45,931.0 (1) On June 30, 2026, Eversource completed the sale of Aquarion. For further information, see Note 17, "Sale of Aquarion Water Distribution Business." (2) These assets are primarily comprised of computer software, hardware and equipment at Eversource Service and buildings at The Rocky River Realty Company. 23 As of June 30, 2026 As of December 31, 2025 (Millions of Dollars) CL&P NSTAR Electric PSNH CL&P NSTAR Electric PSNH Distribution - Electric $ 9,127.4 $ 11,172.3 $ 3,276.7 $ 8,906.0 $ 10,635.7 $ 3,193.8 Transmission - Electric 7,288.2 6,792.1 3,204.8 7,222.5 6,722.9 3,138.7 Solar — 206.8 — — 206.8 — Property, Plant and Equipment, Gross 16,415.6 18,171.2 6,481.5 16,128.5 17,565.4 6,332.5 Less: Accumulated Depreciation (3,181.4) (4,150.5) (1,118.3) (3,081.3) (4,014.2) (1,085.4) Property, Plant and Equipment, Net 13,234.2 14,020.7 5,363.2 13,047.2 13,551.2 5,247.1 Construction Work in Progress 720.5 1,891.3 269.3 576.1 1,757.7 260.6 Total Property, Plant and Equipment, Net $ 13,954.7 $ 15,912.0 $ 5,632.5 $ 13,623.3 $ 15,308.9 $ 5,507.7 4. DERIVATIVE INSTRUMENTS The electric and natural gas companies enter into contracts to purchase and procure energy and energy-related products for their customers, which are subject to price volatility. 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 derivative assets or liabilities on the balance sheets. For the electric and natural gas companies, regulatory assets or regulatory liabilities are recorded to offset the fair values of derivatives, as contract amounts are recovered from, or refunded to, customers in their respective energy supply rates. The mark to market unrealized losses or gains of these derivative contracts are deferred as regulatory assets (if the derivative is a liability) or as regulatory liabilities (if the derivative is an asset). The following table presents the fair values of derivative contracts, categorized by risk type, which are recorded as current or long-term derivative assets or liabilities: NSTAR Electric(Millions of Dollars) Fair Value Hierarchy Commodity Supply and Price Risk Management As of June 30, 2026 As of December 31, 2025 Current Derivative Assets Level 3 $ 115.1 $ 91.0 Long-Term Derivative Liabilities Level 3 (390.3) (753.1) Derivative Contracts at Fair Value with Offsetting Regulatory Amounts Commodity Supply and Price Risk Management: In accordance with Massachusetts clean energy legislation and under the Massachusetts Clean Energy 83D procurement, in June 2018, NSTAR Electric entered into a 20-year power purchase agreement for the purchase of renewable hydroelectric energy and renewable energy attributes from Hydro-Québec. The agreement requires NSTAR Electric to purchase 579 MW of energy per hour through January 2046. Upon notice of commercial operation of the transmission line needed to deliver this energy, received on December 31, 2025, the power purchase agreement was marked to market on the balance sheet. The current and long-term portions of the contract were recorded as derivative assets and derivative liabilities, respectively, and were offset by current and long-term regulatory liabilities and regulatory assets, respectively, reflecting full recovery from or refund to NSTAR Electric’s customers. For the three and six months ended June 30, 2026, gains of $218.3 million and $438.8 million, respectively, from changes in fair value associated with the NSTAR Electric derivative contract were due primarily to changes in the forward energy curve and were deferred in Current Regulatory Liabilities and Long-Term Regulatory Assets on the balance sheet. Fair Value Measurements of Derivative Instruments The fair value of derivative contracts utilizes both observable and unobservable inputs. The fair value is modeled using income techniques, such as discounted cash flow valuations adjusted for assumptions related to exit price. Valuations of derivative contracts using a discounted cash flow methodology include assumptions regarding future energy and energy-related prices, the timing and likelihood of scheduled payments, selection of a discount rate, and also reflect non-performance risk, including credit, using the default probability approach based on the counterparty’s credit rating for assets and the Company’s credit rating for liabilities. Valuations also give consideration to premiums or discounts that would be required by a market participant to arrive at an exit price. Future energy prices that are not quoted in an active market are based on available market data with assumptions of future market dynamics and inflation to address the full time period of the contract. Fair value measurements are prepared and reviewed by individuals with expertise in valuation techniques, pricing of energy-related products, and accounting requirements. For NSTAR Electric’s derivative contract, unobservable inputs for future energy prices using a forward electricity bid price curve are significant to the valuation and are classified as Level 3. Level 3 unobservable inputs utilized in the valuation of NSTAR Electric’s power purchase agreement include energy prices as of June 30, 2026 ranging from $25.88 per MWh through $172.12 per MWh, or a weighted average of $59.56 per MWh, and as of December 31, 2025 ranging from $24.65 per MWh through $145.33 per MWh, or a weighted average of $53.44 per MWh, over the remaining contractual period through 2046. 24 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 in the following table. NSTAR Electric(Millions of Dollars) For the Three Months Ended For the Six Months Ended June 30, 2026 June 30, 2026 Derivatives, Net: Fair Value as of Beginning of Period $ (505.0) $ (662.1) Net Realized/Unrealized Gains Included in Regulatory Assets and Liabilities 218.3 438.8 Settlements 11.5 (51.9) Fair Value as of End of Period $ (275.2) $ (275.2) 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. Equity and available-for-sale debt marketable securities are recorded at fair value. CYAPC and YAEC’s spent nuclear fuel trusts are restricted and are classified in long-term Marketable Securities on the balance sheets. Equity Securities: Eversource's equity securities include CYAPC's and YAEC's marketable securities held in spent nuclear fuel trusts, which had fair values of $170.0 million and $161.8 million as of June 30, 2026 and December 31, 2025, 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. Eversource also holds a trust used to fund certain non-qualified executive benefits. As of June 30, 2026 and December 31, 2025, the securities held in this trust were valued at $3.3 million and $3.5 million, respectively, and were classified as Marketable Securities on the Eversource balance sheets. There were unrealized gains of $0.3 million and unrealized losses of $0.3 million for the three and six months ended June 30, 2026, respectively, and there were unrealized gains of $0.2 million and unrealized losses of $0.1 million for the three and six months ended June 30, 2025, respectively, recorded in Other Income, Net, related to these equity securities. Available-for-Sale Debt Securities: The following is a summary of available-for-sale debt securities, which are held in CYAPC’s and YAEC’s spent nuclear fuel trusts: As of June 30, 2026 As of December 31, 2025 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 $ 151.5 $ 0.1 $ (1.6) $ 150.0 $ 156.5 $ 0.7 $ (1.8) $ 155.4 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. As of June 30, 2026, the contractual maturities of available-for-sale debt securities were as follows: Eversource(Millions of Dollars) Amortized Cost Fair Value Less than one year $ 14.6 $ 14.7 One to five years 39.3 39.4 Six to ten years 34.8 34.5 Greater than ten years 62.8 61.4 Total Debt Securities $ 151.5 $ 150.0 Realized Gains and Losses: Realized gains and losses are offset in long-term liabilities for CYAPC and YAEC and are recorded in Other Income, Net for Eversource's benefit trusts. Eversource utilizes the average cost basis method for the CYAPC and YAEC spent nuclear fuel trusts. 25 Fair Value Measurements: The following table presents the marketable securities recorded at fair value on a recurring basis by the level in which they are classified within the fair value hierarchy: Eversource(Millions of Dollars) As of June 30, 2026 As of December 31, 2025 Level 1: Mutual Funds and Equities $ 173.3 $ 165.3 Money Market Funds 11.9 14.0 Total Level 1 $ 185.2 $ 179.3 Level 2: U.S. Government Issued Debt Securities (Agency and Treasury) $ 82.7 $ 82.0 Corporate Debt Securities 41.5 37.9 Asset-Backed Debt Securities 5.5 6.4 Municipal Bonds 1.1 7.2 Other Fixed Income Securities 7.3 7.9 Total Level 2 $ 138.1 $ 141.4 Total Marketable Securities $ 323.3 $ 320.7 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 and EGMA are parties to a five-year $2.00 billion revolving credit facility. Effective October 11, 2025, the revolving credit facility’s termination date was extended for one additional year to October 11, 2030, pursuant to the extension provisions contained in the existing credit agreement. 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. Effective October 11, 2025, the revolving credit facility’s termination date was extended for one additional year to October 11, 2030, pursuant to the extension provisions contained in the existing credit agreement. This revolving credit facility serves to backstop NSTAR Electric's $650 million commercial paper program. The amount of borrowings outstanding and available under the commercial paper programs were as follows: Borrowings Outstanding as of Available Borrowing Capacity as of Weighted-Average Interest Rate as of June 30, 2026 December 31, 2025 June 30, 2026 December 31, 2025 June 30, 2026 December 31, 2025 (Millions of Dollars) Eversource Parent Commercial Paper Program $ 432.0 $ 1,280.0 $ 1,568.0 $ 720.0 4.00 % 3.98 % NSTAR Electric Commercial Paper Program 63.0 245.4 587.0 404.6 3.87 % 3.87 % There were no borrowings outstanding on the revolving credit facilities as of June 30, 2026 and December 31, 2025. CL&P and PSNH have uncommitted line of credit agreements totaling $375 million and $250 million, respectively, all of which will expire in either September 2026, October 2026 or May 2027. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of June 30, 2026 and December 31, 2025. Amounts outstanding under the commercial paper programs are included in Notes Payable and classified in current liabilities on the Eversource and NSTAR Electric balance sheets, as all borrowings are outstanding for no more than 364 days at one time. As a result of the Yankee Gas long-term debt issuances on July 15, 2026, $62.3 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2026. As a result of the EGMA long-term debt issuances on July 15, 2026, $39.0 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2026. Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of June 30, 2026 and December 31, 2025, there were intercompany loans from Eversource parent to PSNH of $2.1 million and $49.3 million, 26 respectively. As of June 30, 2026, there were intercompany loans from Eversource parent to CL&P of $107.0 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time. Sources and Uses of Cash: The Company expects the future operating cash flows of Eversource, CL&P, NSTAR Electric and PSNH, along with existing borrowing availability and access to both debt and equity markets, will be sufficient to meet any working capital and future operating requirements, and capital investment forecasted opportunities. Long-Term Debt Issuance Authorizations: On March 3, 2026, PSNH filed a petition with the NHPUC requesting authorization to issue up to $200.0 million in long-term debt through December 31, 2026. PSNH has utilized its long-term debt authorizations in place with the NHPUC. On July 17, 2026, NSTAR Electric filed a petition with the DPU requesting authorization to issue up to $3.2 billion in long-term debt through December 31, 2029. 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 NSTAR Electric Debentures 4.65 % $ 350.0 May 2026 May 2031 Repaid 2.70% Debentures at maturity, repaid Series H Senior Notes at maturity, repaid short-term debt, paid capital expenditures and working capital NSTAR Electric Debentures 5.20 % 350.0 May 2026 May 2036 Repaid 2.70% Debentures at maturity, repaid Series H Senior Notes at maturity, repaid short-term debt, paid capital expenditures and working capital NSTAR Electric Debentures 2.70 % (250.0) June 2026 June 2026 Paid at maturity NSTAR Electric Series H Senior Notes 2.75 % (50.0) June 2026 June 2026 Paid at maturity PSNH Series X First Mortgage Bonds 5.35 % 200.0 June 2026 October 2033 Repaid short-term debt, paid capital expenditures and working capital Eversource Parent Series A Junior Notes (1) 6.10 % 750.0 February 2026 August 2056 Repaid Series AA Senior Notes at maturity, repay Series U Senior Notes at maturity, repaid short-term debt, and for general corporate purposes Eversource Parent Series B Junior Notes (2) 6.35 % 750.0 February 2026 August 2056 Repaid Series AA Senior Notes at maturity, repay Series U Senior Notes at maturity, repaid short-term debt, and for general corporate purposes Eversource Parent Series J Senior Notes 3.35 % (250.0) March 2026 March 2026 Paid at maturity Eversource Parent Series AA Senior Notes 4.75 % (450.0) May 2026 May 2026 Paid at maturity Yankee Gas Series AA First Mortgage Bonds 5.22 % 75.0 July 2026 July 2031 Refinance existing indebtedness, fund capital expenditures, and for general corporate purposes Yankee Gas Series BB First Mortgage Bonds 5.61 % 100.0 July 2026 July 2036 Refinance existing indebtedness, fund capital expenditures, and for general corporate purposes EGMA Series G First Mortgage Bonds 5.12 % 100.0 July 2026 July 2031 Refinance existing indebtedness, fund capital expenditures, and for general corporate purposes (1) The Eversource Parent Series A Junior Subordinated Notes bear interest at a fixed rate of 6.10 percent per year from the issuance date of February 26, 2026 to August 14, 2031. Thereafter, the interest rate resets every five years, commencing on August 15, 2031, at a rate per year equal to the five-year U.S. Treasury Rate plus a spread of 2.521 percent. (2) The Eversource Parent Series B Junior Subordinated Notes bear interest at a fixed rate of 6.35 percent per year from the issuance date of February 26, 2026 to August 14, 2036. Thereafter, the interest rate resets every five years, commencing on August 15, 2036, at a rate per year equal to the five-year U.S. Treasury Rate plus a spread of 2.325 percent. In connection with the sale of Aquarion on June 30, 2026, $612.4 million of long-term debt was repaid at closing. As a result of the Yankee Gas long-term debt issuances on July 15, 2026, $90.0 million of current portion of long-term debt was reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2026. 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. 27 PSNH Funding was formed solely to issue RRBs to finance PSNH's unrecovered remaining costs associated with the divestiture of its generation assets. PSNH Funding is considered a VIE primarily because the equity capitalization is insufficient to support its operations. PSNH has the power to direct the significant activities of the VIE and is most closely associated with the VIE as compared to other interest holders. Therefore, PSNH is considered the primary beneficiary and consolidates PSNH Funding in its consolidated financial statements. The following tables summarize the impact of PSNH Funding on PSNH's balance sheets and income statements: (Millions of Dollars) PSNH Balance Sheets: As of June 30, 2026 As of December 31, 2025 Restricted Cash - Current Portion (included in Special Deposits) $ 30.6 $ 30.6 Restricted Cash - Long-Term Portion (included in Other Long-Term Assets) 3.2 3.2 Securitized Stranded Cost (included in Regulatory Assets) 284.5 306.1 Other Regulatory Liabilities (included in Regulatory Liabilities) 7.5 7.3 Accrued Interest (included in Other Current Liabilities) 4.8 5.1 Rate Reduction Bonds - Current Portion 43.2 43.2 Rate Reduction Bonds - Long-Term Portion 259.3 280.9 (Millions of Dollars)PSNH Income Statements: For the Three Months Ended For the Six Months Ended June 30, 2026 June 30, 2025 June 30, 2026 June 30, 2025 Amortization of RRB Principal (included in Amortization of Regulatory Assets, Net) $ 10.8 $ 10.8 $ 21.6 $ 21.6 Interest Expense on RRB Principal (included in Interest Expense) 2.9 3.3 5.8 6.6 8. PENSION BENEFITS AND POSTRETIREMENT BENEFITS OTHER THAN PENSION Eversource provides defined benefit retirement plans (Pension Plans) that cover eligible employees. In addition to the Pension Plans, Eversource maintains non-qualified defined benefit retirement plans (SERP Plans), which provide benefits in excess of Internal Revenue Code limitations to eligible participants consisting of current and retired employees. Eversource also provides defined benefit postretirement plans (PBOP Plans) that provide life insurance and a health reimbursement arrangement created for the purpose of reimbursing retirees and dependents for health insurance premiums and certain medical expenses to eligible employees that meet certain age and service eligibility requirements. The components of net periodic benefit plan expense/(income) for the Pension, SERP and PBOP Plans, prior to amounts capitalized as Property, Plant and Equipment or deferred as regulatory assets/(liabilities) for future recovery or refund, are shown below. The service cost component of net periodic benefit plan expense/(income), less the capitalized portion, is included in Operations and Maintenance expense on the statements of income. The remaining components of net periodic benefit plan expense/(income), less the deferred portion, are included in Other Income, Net on the statements of income. Pension, SERP and PBOP expense/(income) reflected in the statements of cash flows for CL&P, NSTAR Electric and PSNH does not include intercompany allocations of net periodic benefit plan expense/(income), as these amounts are cash settled on a short-term basis. Pension and SERP PBOP For the Three Months Ended June 30, 2026 For the Three Months Ended June 30, 2026 (Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH Service Cost $ 19.3 $ 4.2 $ 3.6 $ 1.7 $ 1.6 $ 0.3 $ 0.2 $ 0.1 Interest Cost 60.1 12.4 12.4 6.3 7.2 1.2 1.9 0.8 Expected Return on Plan Assets (117.3) (24.0) (28.9) (12.3) (22.9) (2.4) (11.3) (1.5) Actuarial Loss/(Gain) 10.6 1.5 3.4 0.4 (0.3) — — — Prior Service Cost/(Credit) 0.2 — 0.1 — (5.4) 0.2 (4.3) 0.1 Total Net Periodic Benefit Plan Income $ (27.1) $ (5.9) $ (9.4) $ (3.9) $ (19.8) $ (0.7) $ (13.5) $ (0.5) Intercompany Income Allocations N/A $ (1.3) $ (1.0) $ (0.3) N/A $ (0.7) $ (0.8) $ (0.3) Pension and SERP PBOP For the Six Months Ended June 30, 2026 For the Six Months Ended June 30, 2026 (Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH Service Cost $ 37.7 $ 8.1 $ 6.8 $ 3.3 $ 3.2 $ 0.6 $ 0.5 $ 0.2 Interest Cost 119.2 24.5 24.6 12.5 14.4 2.5 3.8 1.6 Expected Return on Plan Assets (234.6) (47.9) (57.8) (24.7) (45.6) (5.0) (22.9) (3.0) Actuarial Loss/(Gain) 19.3 2.6 6.2 0.8 (0.7) — — — Prior Service Cost/(Credit) 0.4 — 0.2 — (10.8) 0.5 (8.5) 0.2 Total Net Periodic Benefit Plan Income $ (58.0) $ (12.7) $ (20.0) $ (8.1) $ (39.5) $ (1.4) $ (27.1) $ (1.0) Intercompany Income Allocations N/A $ (3.1) $ (2.5) $ (0.8) N/A $ (1.3) $ (1.6) $ (0.6) 28 Pension and SERP PBOP For the Three Months Ended June 30, 2025 For the Three Months Ended June 30, 2025 (Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH Service Cost $ 17.2 $ 3.8 $ 2.4 $ 1.6 $ 1.6 $ 0.3 $ 0.3 $ 0.1 Interest Cost 64.1 12.9 13.4 6.8 8.0 1.4 2.2 0.8 Expected Return on Plan Assets (113.7) (23.0) (27.7) (12.0) (21.1) (2.4) (10.5) (1.4) Actuarial Loss/(Gain) 11.0 1.3 3.7 0.5 (0.2) — — — Prior Service Cost/(Credit) 0.3 — 0.1 — (5.4) 0.3 (4.3) 0.1 Total Net Periodic Benefit Plan Income $ (21.1) $ (5.0) $ (8.1) $ (3.1) $ (17.1) $ (0.4) $ (12.3) $ (0.4) Intercompany Income Allocations N/A $ (0.5) $ (0.3) $ (0.1) N/A $ (0.5) $ (0.7) $ (0.2) Pension and SERP PBOP For the Six Months Ended June 30, 2025 For the Six Months Ended June 30, 2025 (Millions of Dollars) Eversource CL&P NSTAR Electric PSNH Eversource CL&P NSTAR Electric PSNH Service Cost $ 33.6 $ 7.6 $ 4.9 $ 3.2 $ 3.2 $ 0.5 $ 0.5 $ 0.2 Interest Cost 127.3 25.7 26.4 13.6 16.0 2.8 4.4 1.6 Expected Return on Plan Assets (227.0) (45.9) (55.4) (23.9) (42.3) (4.8) (21.0) (2.8) Actuarial Loss/(Gain) 21.0 2.5 6.9 1.0 (0.5) — — — Prior Service Cost/(Credit) 0.6 — 0.2 — (10.8) 0.6 (8.5) 0.2 Settlement Loss 3.3 — — — — — — — Total Net Periodic Benefit Plan Income $ (41.2) $ (10.1) $ (17.0) $ (6.1) $ (34.4) $ (0.9) $ (24.6) $ (0.8) Intercompany Income Allocations N/A $ (0.4) $ — $ — N/A $ (1.0) $ (1.4) $ (0.4) 9. COMMITMENTS AND CONTINGENCIES A. Environmental Matters Eversource, CL&P, NSTAR Electric and PSNH are subject to environmental laws and regulations intended to mitigate or remove the effect of past operations and improve or maintain the quality of the environment. These laws and regulations require the removal or the remedy of the effect on the environment of the disposal or release of certain specified hazardous substances at current and former operating sites. Eversource, CL&P, NSTAR Electric and PSNH have an active environmental auditing and training program and each believes it is substantially in compliance with all enacted laws and regulations. The number of environmental sites and related reserves for which remediation or long-term monitoring, preliminary site work or site assessment is being performed are as follows: As of June 30, 2026 As of December 31, 2025 Number of Sites Reserve (in millions) Number of Sites Reserve (in millions) Eversource 67 $ 155.2 66 $ 154.3 CL&P 15 15.6 15 14.9 NSTAR Electric 16 8.1 14 7.0 PSNH 8 9.0 8 9.2 Included in the number of sites and reserve amounts above are former MGP sites that were operated several decades ago and manufactured natural gas from coal and other processes, which resulted in certain by-products remaining in the environment that may pose a potential risk to human health and the environment, for which Eversource may have potential liability. Eversource’s reserve balances related to these former MGP sites were $140.0 million and $140.9 million as of June 30, 2026 and December 31, 2025, respectively, and related primarily to the natural gas business segment. These reserve estimates are subjective in nature as they take into consideration several different remediation options at each specific site. The reliability and precision of these estimates can be affected by several factors, including new information concerning either the level of contamination at the site, the extent of Eversource's, CL&P's, NSTAR Electric's and PSNH's responsibility for remediation or the extent of remediation required, recently enacted laws and regulations or changes in cost estimates due to certain economic factors. It is possible that new information or future developments could require a reassessment of the potential exposure to required environmental remediation. As this information becomes available, management will continue to assess the potential exposure and adjust the reserves accordingly. B. Guarantees and Indemnifications In the normal course of business, Eversource parent provides credit assurances on behalf of its subsidiaries, including CL&P, NSTAR Electric and PSNH, in the form of guarantees. Management does not anticipate a material impact to net income or cash flows as a result of these various guarantees and indemnifications. 29 Guarantees issued on behalf of unconsolidated entities, including equity method ownership interests, for which Eversource parent is the guarantor, are recorded at fair value as a liability on the balance sheet at the inception of the guarantee. The fair value of guarantees issued on behalf of unconsolidated entities are recorded within Other Long-Term Liabilities on the balance sheet, and were $0.8 million and $1.3 million as of June 30, 2026 and December 31, 2025, respectively. Eversource regularly reviews performance risk under these guarantee arrangements, and believes the likelihood of payments being required under the guarantees is remote. In the event it becomes probable that Eversource parent will be required to perform under the guarantee, the amount of probable payment will be recorded. On September 30, 2024, Eversource completed the sale of its 50 percent ownership share in the South Fork Wind and Revolution Wind projects to affiliates of Global Infrastructure Partners (GIP). Under the agreement with GIP, Eversource’s existing and certain additional credit support obligations for Revolution Wind are expected to roll off as the project completes construction. On July 9, 2024, Eversource completed the sale of its 50 percent ownership share of Sunrise Wind to Ørsted. Under the agreement with Ørsted, Eversource’s existing credit support obligations for Sunrise Wind were either terminated or indemnified by Ørsted as a result of the sale. 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 previously-owned offshore wind investments: As of June 30, 2026 Company (Obligor) Description Maximum Exposure (in millions) Revolution Wind, LLC and TurbineCo, LLC Offshore wind construction-related purchase agreements with third-party contractors (1) $ 160.6 Eversource Investment LLC, Eversource Investment Service Company LLC and South Fork Class B Member, LLC Offshore wind funding and indemnification obligations (2) 115.5 Eversource Investment LLC Revolution Wind Tax Positions (3) 300.0 Eversource TEI LLC South Fork Wind Tax Equity (4) 50.0 South Fork Wind, LLC Power Purchase Agreement Security (5) 7.1 Various Eversource subsidiaries Surety bonds (6) 33.3 (1) Eversource parent issued guarantees on behalf of its previously 50 percent-owned affiliate, Revolution Wind, LLC, and on behalf of TurbineCo, LLC (successor in interest to North East Offshore, LLC (NEO)), under which Eversource parent agreed to guarantee each entity’s performance of obligations under certain construction-related purchase agreements with third-party contractors, in an aggregate amount not to exceed $682.7 million. Eversource parent’s obligations under the guarantees expire upon the earlier of (i) dates ranging between October 2027 and November 2027 and (ii) full performance of the guaranteed obligations. (2) Eversource parent issued guarantees on behalf of its wholly-owned subsidiary Eversource Investment LLC (EI), which held Eversource's previous investments in offshore wind-related equity method investments until sale, and on behalf of its previously 50 percent-owned affiliate, South Fork Class B Member, LLC, whereby Eversource parent will guarantee each entity’s performance of certain funding obligations of the South Fork and Revolution Wind projects. Eversource parent also guaranteed certain indemnification obligations of EI associated with third-party credit support for EI’s investment in NEO. On September 30, 2024, Eversource parent issued a guaranty on behalf of its wholly-owned subsidiary, Eversource Investment Service Company LLC, whereby Eversource parent will guarantee Eversource Investment Service Company LLC’s performance of certain indemnification obligations during the onshore construction phase of the Revolution Wind project, in an amount not to exceed $100.0 million. These guarantees will not exceed $1.62 billion and expire upon the full performance of the guaranteed obligations. (3) Eversource parent issued a guaranty on behalf of EI in an amount not to exceed $900 million, which was subsequently reduced to an amount not to exceed $300 million, to GIP in order to support certain tax positions related to Revolution Wind project through June 30, 2035. (4) Eversource parent issued a guarantee on behalf of its wholly-owned subsidiary, Eversource TEI LLC, whereby Eversource parent will guarantee Eversource TEI LLC’s performance of certain obligations, in an amount not to exceed $50.0 million, in connection with any remaining obligations under the LLC agreement. Eversource parent’s obligations expire upon the full performance of the guaranteed obligations. (5) Eversource parent issued a guarantee on behalf of its previously 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, January 2044, with the option to extend to January 2049 and (ii) full performance of the guaranteed obligations. (6) Surety bonds expire in 2026 and 2027. 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. Eversource parent entered into a guarantee on behalf of EI, under which Eversource parent would guarantee EI’s obligations under a letter of credit facility with a financial institution that EI may request in an aggregate amount of up to approximately $25 million. As of June 30, 2026, there are no letters of credit issued under this guarantee. The guarantee will remain in effect until full performance of the guaranteed obligations. 30 On September 30, 2024, Eversource entered into an agreement with GIP and Ørsted to contingently provide future credit support up to a maximum of $850 million in guarantees, if required, to support third-party tax equity financing for Revolution Wind. C. 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 New England Transmission Owners’ (NETOs’) base return on equity (ROE) of 11.14 percent that had been utilized since 2006 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 including transmission incentives (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. The NETOs filed an appeal of this decision, which was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit Court). All amounts associated with Opinion No. 531-A on the first complaint period lowering the base ROE of 11.14 percent to 10.57 percent were refunded by 2015. On October 16, 2018, FERC issued an order on all four complaints describing how it intended to address the issues that were remanded by the D.C. Circuit Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. The 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, the preliminary just and reasonable base ROE for the NETOs, which FERC concludes are of average financial risk, is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent. On March 19, 2026, FERC issued Opinion No. 594 in the NETO ROE proceedings, attempting to resolve all four pending complaints dating back to 2011 and respond to the D.C. Circuit Court’s April 14, 2017 decision vacating FERC’s prior decision in the first complaint, which found that the FERC had failed to (1) make an explicit, reasoned finding that the then-existing 11.14 percent base ROE was unjust and unreasonable before imposing a replacement ROE, and (2) adequately justify placing the ROE at the midpoint of the upper half of the zone of reasonableness. In Opinion No. 594, FERC applied a revised ROE methodology that it believes is consistent with its 2024 ROE Order on remand to the Midcontinent ISO (MISO) transmission owners, to satisfy the first step in the FERC process to revise the ROE in a Section 206 proceeding by finding the NETOs’ base ROE of 11.14 percent is unjust and unreasonable. FERC then found the just and reasonable replacement base ROE to be 9.57 percent with an incentive cap of 12.09 percent for the first complaint period (October 1, 2011 – December 31, 2012) and applied this same ROE prospectively, effective October 16, 2014, the date of the first complaint order vacated by the D.C. Circuit Court. FERC directed the NETOs to issue refunds with interest for the applicable refund periods. This decision decreases the allowed base ROE of 10.57 percent with an incentive cap of 11.74 percent to a base ROE of 9.57 percent with an incentive cap of 12.09 percent. The second, third and fourth NETO ROE complaints were dismissed as part of the decision, and FERC did not direct any refunds for the periods associated with those proceedings. On April 14, 2026, FERC granted an extension of the refund deadline to May 20, 2027. On April 14, 2026, Eversource and Avangrid filed a joint motion requesting a stay of the retroactive refund obligation applicable to the period October 16, 2014 through March 19, 2026 (retroactive refund period) with the D.C. Circuit Court. On April 20, 2026, the NETOs submitted to FERC a request for rehearing of Opinion No. 594 highlighting several deficiencies including but not limited to the unlawful retroactive refund period with interest extended beyond the 15-month statutory relief authority granted in Section 206(b) of the Federal Power Act, the FERC not proving that the previously approved 11.14 percent base ROE was unjust and unreasonable as remanded by the D.C. Circuit Court, the flawed methodologies applied in setting the replacement 9.57 percent base ROE, failing to comply with the requirement for FERC to use data that is relevant to the current period at the time of the decision for the NETOs’ prospective ROE, and procedural issues related to overlapping complaints. On May 21, 2026, FERC issued an order denying the request for rehearing by operation of law. The NETOs filed an appeal of Opinion No. 594 and the FERC denial of rehearing by operation of law with the D.C. Circuit Court on June 5, 2026. On April 30, 2026, the NETOs submitted a Federal Power Act Section 205 filing to FERC, which is a formal request by a public utility to change the ROE rate prospectively and requires the utility to prove the proposed change is just and reasonable. The NETOs proposed a replacement base ROE of 11.39 percent, resulting in an incentive cap of 12.89 percent, which is based on current market data utilizing FERC’s ROE methodology from Opinion No. 594. The NETOs requested an effective date of June 30, 2026. On June 29, 2026, FERC issued an order finding the proposed ROE has not been shown to be just and reasonable, suspending the increase until November 30, 2026, subject to refund, and initiating paper hearing procedures. Initial briefs are due in the paper hearing on August 28, 2026, with reply briefs due on September 28, 2026. As a result of the March 19, 2026 FERC decision, Eversource has determined that a refund is probable and that a range of refunds is reasonably estimable. Based on Eversource’s current evaluation of the relevant facts and circumstances, the Company has estimated a range of reasonably possible pre-tax refunds of $62.0 million to $968.4 million, which includes a range of interest of $30.1 million to $271.5 million, as of June 30, 2026. The low end of the estimated range of refunds reflects estimated refunds associated with the fifteen-month first complaint period, including interest. The high end of the estimated range of refunds includes the refunds associated with the first complaint period, as well as estimated refunds for the retroactive refund period from October 16, 2014 through March 19, 2026, including interest, in the pre-tax amount of approximately $906.4 million. The range of refund estimates use the 9.57 percent replacement ROE and incentive cap of 12.09 percent prescribed 31 in the March 19, 2026 FERC decision. Based on Eversource’s legal assessment of the Federal Power Act and the legal and regulatory deficiencies underlying this decision as identified in the rehearing request, including that the retroactive application is inconsistent with the statutory limitations under the Federal Power Act, Eversource does not believe that refunds at the high end of the range for the retroactive period are probable. Eversource continues to challenge the March 19, 2026 FERC decision, but cannot predict the ultimate outcome of these proceedings. The Company has recorded a current regulatory liability for revenues subject to refund of $62.0 million (pre-tax) as of June 30, 2026, which represents the low end of the range, as no amount within this range is considered a better estimate. The regulatory liability recorded reflects the difference between the billed 10.57 percent base ROE and the new 9.57 percent base ROE for the first complaint period, including interest. The liability consists of $29.8 million, $24.6 million and $7.6 million for CL&P, NSTAR Electric and PSNH, respectively, of which $14.4 million, $12.0 million and $3.7 million is accrued interest, respectively, as of June 30, 2026. The revenues subject to refund were recorded as a reduction to Operating Revenues, and the accrued interest was recorded as an increase to Interest Expense in the statements of income. Eversource does not have any other reserves recorded for the other complaint periods, as these remaining complaints were dismissed. The Company’s estimates are based on currently available information; however, it is reasonably possible that the ultimate resolution of this matter may result in a refund in excess of the amount accrued, and such additional losses could have a material impact on the financial condition, results of operations, and cash flows in a future period. D. Spent Nuclear Fuel Obligations - Yankee Companies CL&P, NSTAR Electric and PSNH have plant closure and fuel storage cost obligations to the Yankee Companies, which have each completed the physical decommissioning of their respective nuclear power facilities and are now engaged in the long-term storage of their spent fuel. The Yankee Companies fund these costs through litigation proceeds received from the DOE and, to the extent necessary, through wholesale, FERC-approved rates charged under power purchase agreements with several New England utilities, including CL&P, NSTAR Electric and PSNH. CL&P, NSTAR Electric and PSNH, in turn recover these costs from their customers through state regulatory commission-approved retail rates. The Yankee Companies collect amounts that management believes are adequate to recover the remaining plant closure and fuel storage cost estimates for the respective plants. Management believes CL&P and NSTAR Electric will recover their shares of these obligations from their customers. PSNH has recovered its total share of these costs from its customers. Spent Nuclear Fuel Litigation: The Yankee Companies have filed complaints against the DOE in the Court of Federal Claims seeking monetary damages resulting from the DOE's failure to accept delivery of, and provide for a permanent facility to store, spent nuclear fuel pursuant to the terms of the 1983 spent fuel and high-level waste disposal contracts between the Yankee Companies and the DOE. The court previously awarded the Yankee Companies damages for Phases I, II, III, and IV of litigation resulting from the DOE's failure to meet its contractual obligations. These Phases covered damages incurred in the years 1998 through 2016, and the awarded damages have been received by the Yankee Companies with certain amounts of the damages refunded to their customers. DOE Phase V Damages - In March 2021, the Yankee Companies filed Phase V lawsuits against the DOE seeking damages for its continued failure to accept spent nuclear fuel, later expanding the claims to include 2021 costs, bringing total claimed damages to $153.5 million. The parties reached a $145 million agreement in principle to settle the Phase V complaint, approved in November 2024. The Department of Justice filed a notice of appeal in January 2025 on an issue outside the scope of the settlement. Oral arguments were held on July 7, 2026. DOE Phase VI Damages – On March 31, 2026, each of the Yankee Companies filed a sixth set of lawsuits against the DOE in the Court of Federal Claims. The Yankee Companies are seeking monetary damages for CYAPC, YAEC and MYAPC, resulting from the DOE’s failure to begin accepting spent nuclear fuel for disposal covering the years from 2022 to 2025 (DOE Phase VI). E. Offshore Wind Sale and Contingent Liability On July 9, 2024, Eversource completed the sale of its 50 percent ownership share of Sunrise Wind to Ørsted for adjusted proceeds of $152 million. Ørsted paid Eversource $118 million at the closing of the sale transaction and remaining proceeds of $34 million will be paid after onshore construction is completed and certain other construction milestones are achieved. With completion of the sale, Eversource does not have any ongoing financial obligations associated with Sunrise Wind. On September 30, 2024, Eversource completed the sale of its 50 percent ownership share in the South Fork Wind and Revolution Wind projects to GIP for adjusted gross proceeds of $745 million, which were received at closing. As part of the sale, Eversource and GIP agreed to make certain post-closing purchase price adjustment payments that will impact the final purchase price. The post-closing purchase price adjustment payments include cost sharing obligations that require Eversource to share equally in GIP’s funding obligations up to an effective cap of approximately $240 million of incremental capital expenditure overruns incurred during the construction phase for Revolution Wind, after which Eversource will have responsibility for GIP’s obligations for any additional capital expenditure overruns in excess of this amount. The purchase price is also subject to post-closing adjustments as a result of final project economics, which includes Eversource’s obligation to maintain GIP’s internal rate of return through the construction period for each project as specified in the agreement. For Revolution Wind, purchase price adjustment payments are expected to be completed in late 2026. South Fork Wind has achieved commercial operation, and Eversource made a purchase price adjustment payment related to this project in June 2025. All matters relating to South Fork Wind have been resolved with no material impacts. Upon the completion of the sales in 2024, Eversource recorded a contingent liability of $365 million, reflecting its estimate of the future obligations under the terms of the sale to GIP. The total sales proceeds were compared to the carrying value of the investments, including the estimate of liability for-post-closing adjustment payments to GIP, and Eversource recognized an aggregate after-tax loss on the sales of its offshore wind investments of $524 million, which included a net $60 million increase in income tax expense including an increase in the valuation allowance for unused capital losses in 2024. 32 In the third quarter of 2025, Eversource received an updated report on the construction status of Revolution Wind, which included revised projections of total construction costs. The revised cost projections reflected known and quantifiable cost increases, including those associated with the impacts of damage to the wind turbine installation vessel, insurance costs, tariff impacts, and costs incurred as a result of the stop-work order for Revolution Wind received on August 22, 2025 from the Bureau of Ocean Energy Management that halted all offshore wind construction activities through September 22, 2025. Based on those developments, Eversource recognized a pre-tax charge of $284 million in the third quarter of 2025 as a result of the aggregate impact of these items to increase the liability for purchase price adjustments associated with the offshore wind projects. In the second quarter of 2026, Eversource received revised projections of total construction costs associated with Revolution Wind, which included quantifiable cost increases. As a result, Eversource recognized a pre-tax charge of $194 million in the second quarter of 2026 to increase the liability for purchase price adjustments associated with the Revolution Wind project. Payments made in the first half of 2026 and 2025 of $233.0 million and $68.6 million, respectively, reduced the contingent liability and were reflected within investing activities on the statement of cash flows. Payments made in 2026 related to cost overruns for the Revolution Wind project paid to GIP and payment in 2025 related to a purchase price adjustment payment for the South Fork Wind project paid to GIP. Eversource continually evaluates the contingent liability and will reassess the balance as new information becomes available. Based on most recent updates on the construction status of Revolution Wind and other information currently available, Eversource believes that the contingent liability balance as of June 30, 2026 is an adequate estimate to cover this contingent liability for purchase price adjustments. As of June 30, 2026 and December 31, 2025, the contingent liability totaled $409.2 million and $448.2 million, respectively, and is recorded as a current liability on Eversource’s balance sheets, based upon the timing of expected payments to GIP. Eversource relies on information that it receives from the project owners for the construction-related, delay-related, and insurance-related costs of Revolution Wind. Eversource uses its judgment to adjust, as needed, its expected obligations to GIP while construction of Revolution Wind is completed. New information or future developments that arise as the construction of Revolution Wind progresses will necessitate a reassessment of the estimated liability to GIP. The Company reviews available projections of total construction costs, including the latest cost estimates and project timeline, to determine if any changes to this liability are warranted. It is reasonably possible that as additional updated cost estimates become available, and if additional cost overruns materialize or other adverse changes in facts, regulations and circumstances occur, there could be additional losses and increases to the offshore wind contingent liability, which could be material. The Company will continue to monitor developments and evaluate potential exposures related to this contingency and will revise its estimated liability as additional information becomes available. Contingencies are evaluated using the best information available at the time the financial statements are published, and this assessment involves judgments and assumptions about future events. Factors that could increase the obligation to GIP include construction cost overruns for Revolution Wind as well as the timing and extent of construction delays, which would impact the economics associated with the purchase price adjustment, and the eligibility for federal investment tax credits for Revolution Wind at a value lower than assumed and included in the purchase price. The purchase price of Revolution Wind included the sales value related to a 40 percent level of federal investment tax credits. A change in the expected value or qualification of investment tax credit adders could result in a significant loss in a future period. Total net proceeds could also be adjusted for a benefit due to Eversource if there are lower operation costs or higher availability of the projects through the period that is four years following the commercial operation of Revolution Wind. 33 10. FAIR VALUE OF FINANCIAL INSTRUMENTS The following methods and assumptions were used to estimate the fair value of each of the following financial instruments: Preferred Stock, Long-Term Debt and Rate Reduction Bonds: The fair value of CL&P's and NSTAR Electric's preferred stock is based upon pricing models that incorporate interest rates and other market factors, valuations or trades of similar securities and cash flow projections. The fair value of long-term debt and RRB debt securities is based upon pricing models that incorporate quoted market prices for those issues or similar issues adjusted for market conditions, credit ratings of the respective companies and treasury benchmark yields. The fair values provided in the table below are classified as Level 2 within the fair value hierarchy. Carrying amounts and estimated fair values are as follows: Eversource CL&P NSTAR Electric PSNH (Millions of Dollars) Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value As of June 30, 2026: Preferred Stock Not Subject to Mandatory Redemption $ 155.6 $ 123.7 $ 116.2 $ 91.1 $ 43.0 $ 32.6 $ — $ — Long-Term Debt 29,111.6 27,713.4 5,111.3 4,782.8 6,341.8 6,089.2 2,234.5 2,054.1 Rate Reduction Bonds 302.5 294.6 — — — — 302.5 294.6 As of December 31, 2025: Preferred Stock Not Subject to Mandatory Redemption $ 155.6 $ 126.1 $ 116.2 $ 92.9 $ 43.0 $ 33.2 $ — $ — Long-Term Debt 28,265.4 27,055.5 5,110.1 4,844.7 5,945.6 5,752.6 2,031.3 1,874.8 Rate Reduction Bonds 324.1 320.2 — — — — 324.1 320.2 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 1D, "Summary of Significant Accounting Policies – Fair Value Measurements," for the fair value measurement policy and the fair value hierarchy. 11. ACCUMULATED OTHER COMPREHENSIVE INCOME/(LOSS) The changes in accumulated other comprehensive income/(loss) by component, net of tax, are as follows: For the Six Months Ended June 30, 2026 For the Six Months Ended June 30, 2025 Eversource (Millions of Dollars) Qualified Cash Flow Hedging Instruments Defined Benefit Plans Total Qualified Cash Flow Hedging Instruments Defined Benefit Plans Total Balance as of Beginning of Period $ (0.4) $ (20.1) $ (20.5) $ (0.4) $ (26.1) $ (26.5) OCI Before Reclassifications — 0.4 0.4 — (0.9) (0.9) Amounts Reclassified from AOCI — 0.8 0.8 — 3.5 3.5 Net OCI — 1.2 1.2 — 2.6 2.6 Balance as of End of Period $ (0.4) $ (18.9) $ (19.3) $ (0.4) $ (23.5) $ (23.9) 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 six months ended June 30, 2025. 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 June 30, 2026 and December 31, 2025 Issued as of Par Value June 30, 2026 December 31, 2025 Eversource $ 5 410,000,000 383,143,545 382,854,501 CL&P $ 10 24,500,000 6,035,205 6,035,205 NSTAR Electric $ 1 100,000,000 200 200 PSNH $ 1 100,000,000 301 301 34 Common Share Issuances: On May 30, 2025, Eversource entered into an equity distribution agreement pursuant to which it may offer and sell up to $1.2 billion of its common shares from time to time through an “at-the-market” (ATM) equity offering program. Eversource may issue and sell its common shares through its sales agents during the term of this agreement. Shares were offered in transactions on the New York Stock Exchange, in the over-the-counter market, through negotiated transactions or otherwise. Sales may be made at either market prices prevailing at the time of sale, at prices related to such prevailing market prices or at negotiated prices. In 2025, Eversource issued 7,130,134 common shares, which resulted in proceeds of $465.4 million, net of issuance costs. In the second quarter of 2026, Eversource issued 289,044 common shares, which resulted in proceeds of $20.2 million, net of issuance costs. Eversource used the net proceeds received for general corporate purposes. Treasury Shares: As of June 30, 2026 and December 31, 2025, there were 6,545,208 and 7,437,621 Eversource common shares held as treasury shares, respectively. As of June 30, 2026 and December 31, 2025, there were 376,598,337 and 375,416,880 Eversource common shares outstanding, respectively. Eversource issues treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan. The issuance of treasury shares represents a non-cash transaction, as the treasury shares were used to fulfill Eversource's obligations that require the issuance of common shares. 13. COMMON SHAREHOLDERS' EQUITY AND NONCONTROLLING INTERESTS Dividends on the preferred stock of CL&P and NSTAR Electric totaled $1.9 million for each of the three months ended June 30, 2026 and 2025 and $3.8 million for each of the six months ended June 30, 2026 and 2025. These dividends were presented as Net Income Attributable to Noncontrolling Interests on the Eversource statements of income. Noncontrolling Interest – Preferred Stock of Subsidiaries on the Eversource balance sheets totaled $155.6 million as of June 30, 2026 and December 31, 2025. 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 earnings per share is computed based upon the weighted average number of common shares outstanding during each period. Diluted earnings per share is computed on the basis of the weighted average number of common shares outstanding plus the potential dilutive effect of certain share-based compensation awards as if they were converted into outstanding common shares. The dilutive effect of unvested RSU and performance share awards is calculated using the treasury stock method. RSU and performance share awards are included in basic weighted average common shares outstanding as of the date that all necessary vesting conditions have been satisfied. For the three and six months ended June 30, 2026 and 2025, there were no antidilutive share awards excluded from the computation of diluted EPS. The following table sets forth the components of basic and diluted earnings per share: Eversource(Millions of Dollars, except share information) For the Three Months Ended For the Six Months Ended June 30, 2026 June 30, 2025 June 30, 2026 June 30, 2025 Net Income Attributable to Common Shareholders $ 53.7 $ 352.7 $ 660.5 $ 903.5 Weighted Average Common Shares Outstanding: Basic 376,488,004 368,661,995 376,257,047 367,991,121 Dilutive Effect 510,875 255,192 534,200 306,283 Diluted 376,998,879 368,917,187 376,791,247 368,297,404 Basic Earnings Per Common Share $ 0.14 $ 0.96 $ 1.76 $ 2.46 Diluted Earnings Per Common Share $ 0.14 $ 0.96 $ 1.75 $ 2.45 35 15. REVENUES The following tables present operating revenues disaggregated by revenue source: For the Three Months Ended June 30, 2026 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 $ 1,071.2 $ 317.3 $ — $ 44.6 $ — $ — $ 1,433.1 Commercial 778.9 170.9 — 18.9 — (3.1) 965.6 Industrial 99.9 58.1 — 1.2 — (7.0) 152.2 Total Retail Tariff Sales Revenues 1,950.0 546.3 — 64.7 — (10.1) 2,550.9 Wholesale Transmission Revenues — — 610.8 — — (453.0) 157.8 Wholesale Market Sales Revenues 219.9 24.8 — 1.2 — — 245.9 Other Revenues from Contracts with Customers 24.5 1.7 3.1 0.6 439.8 (442.9) 26.8 Total Revenues from Contracts with Customers 2,194.4 572.8 613.9 66.5 439.8 (906.0) 2,981.4 Alternative Revenue Programs (16.1) (45.2) (32.9) (4.4) — 13.8 (84.8) Other Revenues 5.2 1.1 — 0.3 — — 6.6 Total Operating Revenues $ 2,183.5 $ 528.7 $ 581.0 $ 62.4 $ 439.8 $ (892.2) $ 2,903.2 For the Six Months Ended June 30, 2026 Eversource(Millions of Dollars) Electric Distribution Natural Gas Distribution Electric Transmission Water Distribution Other Eliminations Total Revenues from Contracts with Customers Retail Tariff Sales Residential $ 2,538.9 $ 1,162.0 $ — $ 77.4 $ — $ — $ 3,778.3 Commercial 1,612.0 561.3 — 35.1 — (6.6) 2,201.8 Industrial 197.7 141.7 — 2.3 — (13.6) 328.1 Total Retail Tariff Sales Revenues 4,348.6 1,865.0 — 114.8 — (20.2) 6,308.2 Wholesale Transmission Revenues — — 1,243.1 — — (919.4) 323.7 Wholesale Market Sales Revenues 741.1 84.2 — 2.3 — — 827.6 Other Revenues from Contracts with Customers 44.9 3.3 14.2 1.3 924.3 (928.1) 59.9 Total Revenues from Contracts with Customers 5,134.6 1,952.5 1,257.3 118.4 924.3 (1,867.7) 7,519.4 Alternative Revenue Programs (21.5) (52.8) (91.8) (2.8) — 43.5 (125.4) Other Revenues 10.9 2.1 0.2 0.4 — — 13.6 Total Operating Revenues $ 5,124.0 $ 1,901.8 $ 1,165.7 $ 116.0 $ 924.3 $ (1,824.2) $ 7,407.6 For the Three Months Ended June 30, 2025 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 $ 1,104.2 $ 234.1 $ — $ 40.7 $ — $ — $ 1,379.0 Commercial 771.7 125.5 — 17.7 — (1.9) 913.0 Industrial 102.7 47.7 — 1.2 — (6.8) 144.8 Total Retail Tariff Sales Revenues 1,978.6 407.3 — 59.6 — (8.7) 2,436.8 Wholesale Transmission Revenues — — 596.4 — — (439.6) 156.8 Wholesale Market Sales Revenues 155.2 48.9 — 1.1 — — 205.2 Other Revenues from Contracts with Customers 22.2 1.6 3.3 0.7 405.8 (404.6) 29.0 Total Revenues from Contracts with Customers 2,156.0 457.8 599.7 61.4 405.8 (852.9) 2,827.8 Alternative Revenue Programs 7.6 2.3 (31.1) (0.6) — 28.2 6.4 Other Revenues 2.8 0.7 0.1 0.3 — — 3.9 Total Operating Revenues $ 2,166.4 $ 460.8 $ 568.7 $ 61.1 $ 405.8 $ (824.7) $ 2,838.1 36 For the Six Months Ended June 30, 2025 Eversource(Millions of Dollars) Electric Distribution Natural Gas Distribution Electric Transmission Water Distribution Other Eliminations Total Revenues from Contracts with Customers Retail Tariff Sales Residential $ 2,593.6 $ 930.6 $ — $ 72.0 $ — $ — $ 3,596.2 Commercial 1,579.3 431.5 — 33.1 — (4.0) 2,039.9 Industrial 206.8 115.5 — 2.1 — (12.6) 311.8 Total Retail Tariff Sales Revenues 4,379.7 1,477.6 — 107.2 — (16.6) 5,947.9 Wholesale Transmission Revenues — — 1,190.4 — — (878.9) 311.5 Wholesale Market Sales Revenues 502.9 111.3 — 2.1 — — 616.3 Other Revenues from Contracts with Customers 43.0 2.9 6.9 1.3 844.9 (840.4) 58.6 Total Revenues from Contracts with Customers 4,925.6 1,591.8 1,197.3 110.6 844.9 (1,735.9) 6,934.3 Alternative Revenue Programs 9.8 8.6 (81.0) 0.1 — 73.4 10.9 Other Revenues 8.7 1.7 0.2 0.6 — — 11.2 Total Operating Revenues $ 4,944.1 $ 1,602.1 $ 1,116.5 $ 111.3 $ 844.9 $ (1,662.5) $ 6,956.4 For the Three Months Ended June 30, 2026 For the Three Months Ended June 30, 2025 (Millions of Dollars) CL&P NSTAR Electric PSNH CL&P NSTAR Electric PSNH Revenues from Contracts with Customers Retail Tariff Sales Residential $ 538.9 $ 371.9 $ 160.4 $ 583.5 $ 379.6 $ 141.1 Commercial 273.8 417.3 88.3 309.5 377.8 85.1 Industrial 35.8 38.5 25.6 44.0 33.2 25.5 Total Retail Tariff Sales Revenues 848.5 827.7 274.3 937.0 790.6 251.7 Wholesale Transmission Revenues 260.6 228.4 121.8 247.1 226.4 122.9 Wholesale Market Sales Revenues 131.6 78.8 9.5 114.7 32.1 8.4 Other Revenues from Contracts with Customers 8.1 14.8 5.1 8.6 12.3 5.1 Total Revenues from Contracts with Customers 1,248.8 1,149.7 410.7 1,307.4 1,061.4 388.1 Alternative Revenue Programs (8.6) (29.9) (10.5) 3.2 (7.9) (18.8) Other Revenues 2.1 2.2 0.9 0.1 2.2 0.6 Eliminations (192.7) (184.1) (67.2) (178.5) (186.8) (66.8) Total Operating Revenues $ 1,049.6 $ 937.9 $ 333.9 $ 1,132.2 $ 868.9 $ 303.1 For the Six Months Ended June 30, 2026 For the Six Months Ended June 30, 2025 (Millions of Dollars) CL&P NSTAR Electric PSNH CL&P NSTAR Electric PSNH Revenues from Contracts with Customers Retail Tariff Sales Residential $ 1,326.7 $ 843.0 $ 369.2 $ 1,384.8 $ 885.7 $ 323.1 Commercial 578.2 851.8 183.0 653.6 753.5 173.4 Industrial 74.8 73.2 49.7 92.4 64.1 50.3 Total Retail Tariff Sales Revenues 1,979.7 1,768.0 601.9 2,130.8 1,703.3 546.8 Wholesale Transmission Revenues 529.8 464.8 248.5 498.2 445.1 247.1 Wholesale Market Sales Revenues 500.2 222.2 18.7 394.7 89.4 18.8 Other Revenues from Contracts with Customers 23.2 28.2 8.8 17.2 24.3 9.5 Total Revenues from Contracts with Customers 3,032.9 2,483.2 877.9 3,040.9 2,262.1 822.2 Alternative Revenue Programs (41.1) (46.2) (26.0) (15.7) (17.0) (38.5) Other Revenues 4.4 4.6 2.1 2.8 4.6 1.5 Eliminations (378.4) (372.6) (136.5) (354.6) (366.5) (134.1) Total Operating Revenues $ 2,617.8 $ 2,069.0 $ 717.5 $ 2,673.4 $ 1,883.2 $ 651.1 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. The Electric Distribution segment consists of the rate-regulated distribution businesses of CL&P, NSTAR Electric and PSNH, and includes the results of NSTAR Electric's solar power facilities. The Electric Transmission segment consists of the rate-regulated electric transmission businesses of CL&P, NSTAR Electric and PSNH. The Natural Gas Distribution segment consists of the rate-regulated businesses of Yankee Gas, NSTAR Gas and EGMA. These reportable segments represent 37 substantially all of Eversource's total consolidated revenues. Revenues from the sale of electricity and natural gas and water primarily are derived from residential, commercial and industrial customers and are not dependent on any single customer. On June 30, 2026, Eversource completed the sale of Aquarion. The Water Distribution segment, which consists of the rate-regulated business of Aquarion, no longer qualifies as an active reportable segment as of the end of the current quarter. Management has elected to continue presenting the results of the Aquarion water distribution business as a separate reportable segment for the current periods and comparative prior periods. See Note 17, “Sale of Aquarion Water Distribution Business” for further information. 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 chief operating decision maker uses the net income of each reportable segment to evaluate return generated from assets and decide how to reinvest profits and allocate resources, to monitor budget-to-actual results, in the planning and forecasting process, in determining compensation achievement, and in benchmarking to Eversource’s peers. Eversource’s chief operating decision maker is its chief executive officer. The accounting policies of the segments are the same as those described in the summary of significant accounting policies. 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 a natural gas pipeline owned by Enbridge, Inc, and its former offshore wind investments in three offshore wind projects that were sold in 2024 and post-sale obligations. 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 June 30, 2026 Eversource(Millions of Dollars) Electric Distribution Natural Gas Distribution Electric Transmission Water Distribution Other Eliminations Total Operating Revenues $ 2,183.5 $ 528.7 $ 581.0 $ 62.4 $ 439.8 $ (892.2) $ 2,903.2 Depreciation and Amortization (98.4) (85.2) (125.1) (13.9) (60.9) 3.9 (379.6) Operations and Maintenance (1) Operations, Excluding Storm Costs (95.5) (33.9) (37.9) Corporate Shared Services (121.1) (29.9) (20.5) Storm Costs (11.5) — — Employee Benefits (42.9) (17.7) (12.6) Uncollectible Expense (37.4) (18.4) — Other (51.7) (6.0) (19.3) Total Operations and Maintenance (360.1) (105.9) (90.3) (25.4) (346.2) 447.5 (480.4) Purchased Power, Purchased Natural Gas and Transmission, Other Taxes and Energy Efficiency (2) (1,463.3) (282.1) (80.8) (6.6) 1.1 440.8 (1,390.9) Sale of Aquarion — — — (111.4) — — (111.4) Operating Income/(Loss) 261.7 55.5 284.8 (94.9) 33.8 — 540.9 Interest Expense (107.6) (34.8) (55.6) (7.3) (188.4) 38.3 (355.4) Loss on Offshore Wind — — — — (194.0) — (194.0) Interest Income 22.5 9.9 0.2 — 38.3 (38.3) 32.6 Other Income, Net 44.7 10.0 14.2 0.8 135.4 (93.7) 111.4 Income Tax (Expense)/Benefit (49.7) (10.9) (59.2) 1.6 38.3 — (79.9) Net Income/(Loss) 171.6 29.7 184.4 (99.8) (136.6) (93.7) 55.6 Net Income Attributable to Noncontrolling Interests (1.2) — (0.7) — — — (1.9) Net Income/(Loss) Attributable to Common Shareholders $ 170.4 $ 29.7 $ 183.7 $ (99.8) $ (136.6) $ (93.7) $ 53.7 38 For the Six Months Ended June 30, 2026 Eversource(Millions of Dollars) Electric Distribution Natural Gas Distribution Electric Transmission Water Distribution Other Eliminations Total Operating Revenues $ 5,124.0 $ 1,901.8 $ 1,165.7 $ 116.0 $ 924.3 $ (1,824.2) $ 7,407.6 Depreciation and Amortization (640.1) (182.7) (240.4) (26.2) (121.5) 8.1 (1,202.8) Operations and Maintenance (1) Operations, Excluding Storm Costs (202.4) (84.5) (72.5) Corporate Shared Services (242.7) (60.3) (42.2) Storm Costs (40.4) — — Employee Benefits (82.0) (38.5) (24.3) Uncollectible Expense (73.0) (51.9) — Other (83.0) (6.5) (35.8) Total Operations and Maintenance (723.5) (241.7) (174.8) (48.1) (737.9) 938.6 (987.4) Purchased Power, Purchased Natural Gas and Transmission, Other Taxes and Energy Efficiency (2) (3,198.4) (999.9) (154.8) (13.7) 0.3 877.5 (3,489.0) Sale of Aquarion — — — (111.4) — — (111.4) Operating Income/(Loss) 562.0 477.5 595.7 (83.4) 65.2 — 1,617.0 Interest Expense (207.7) (68.8) (138.6) (14.5) (368.6) 77.5 (720.7) Loss on Offshore Wind — — — — (194.0) — (194.0) Interest Income 43.0 17.7 0.3 — 77.5 (77.5) 61.0 Other Income, Net 89.7 16.8 28.4 2.5 827.5 (780.7) 184.2 Income Tax (Expense)/Benefit (111.6) (118.1) (120.2) 1.9 64.8 — (283.2) Net Income/(Loss) 375.4 325.1 365.6 (93.5) 472.4 (780.7) 664.3 Net Income Attributable to Noncontrolling Interests (2.3) — (1.5) — — — (3.8) Net Income/(Loss) Attributable to Common Shareholders $ 373.1 $ 325.1 $ 364.1 $ (93.5) $ 472.4 $ (780.7) $ 660.5 Cash Flows Used for Investments in Plant $ 951.4 $ 333.9 $ 531.3 $ 72.0 $ 134.9 $ — $ 2,023.5 For the Three Months Ended June 30, 2025 Eversource(Millions of Dollars) Electric Distribution Natural Gas Distribution Electric Transmission Water Distribution Other Eliminations Total Operating Revenues $ 2,166.4 $ 460.8 $ 568.7 $ 61.1 $ 405.8 $ (824.7) $ 2,838.1 Depreciation and Amortization (265.8) (57.7) (109.6) (11.8) (53.4) 3.6 (494.7) Operations and Maintenance (1) Operations, Excluding Storm Costs (96.5) (40.8) (37.0) Corporate Shared Services (105.7) (28.0) (16.9) Storm Costs (21.9) — — Employee Benefits (47.3) (17.2) (11.9) Uncollectible Expense (41.1) (13.4) — Other (39.6) (5.1) (18.3) Total Operations and Maintenance (352.1) (104.5) (84.1) (23.3) (313.3) 409.7 (467.6) Purchased Power, Purchased Natural Gas and Transmission, Other Taxes and Energy Efficiency (2) (1,307.9) (235.4) (73.2) (6.7) (1.0) 411.4 (1,212.8) Operating Income 240.6 63.2 301.8 19.3 38.1 — 663.0 Interest Expense (95.4) (28.1) (28.3) (7.7) (176.9) 43.2 (293.2) Interest Income 24.8 5.8 0.2 — 43.2 (43.2) 30.8 Other Income, Net 39.3 8.9 9.6 1.4 433.9 (428.5) 64.6 Income Tax (Expense)/Benefit (46.6) (14.5) (74.6) 1.4 23.7 — (110.6) Net Income 162.7 35.3 208.7 14.4 362.0 (428.5) 354.6 Net Income Attributable to Noncontrolling Interests (1.2) — (0.7) — — — (1.9) Net Income Attributable to Common Shareholders $ 161.5 $ 35.3 $ 208.0 $ 14.4 $ 362.0 $ (428.5) $ 352.7 39 For the Six Months Ended June 30, 2025 Eversource(Millions of Dollars) Electric Distribution Natural Gas Distribution Electric Transmission Water Distribution Other Eliminations Total Operating Revenues $ 4,944.1 $ 1,602.1 $ 1,116.5 $ 111.3 $ 844.9 $ (1,662.5) $ 6,956.4 Depreciation and Amortization (830.6) (162.1) (216.3) (23.0) (104.1) 6.3 (1,329.8) Operations and Maintenance (1) Operations, Excluding Storm Costs (198.1) (87.1) (68.5) Corporate Shared Services (222.0) (58.3) (38.7) Storm Costs (41.8) — — Employee Benefits (95.8) (35.7) (23.6) Uncollectible Expense (84.8) (43.4) — Other (67.3) (2.9) (29.2) Total Operations and Maintenance (709.8) (227.4) (160.0) (46.1) (662.4) 850.7 (955.0) Purchased Power, Purchased Natural Gas and Transmission, Other Taxes and Energy Efficiency (2) (2,888.4) (840.7) (142.8) (13.4) (2.4) 805.5 (3,082.2) Operating Income 515.3 371.9 597.4 28.8 76.0 — 1,589.4 Interest Expense (186.5) (56.5) (66.8) (15.5) (355.3) 86.6 (594.0) Interest Income 52.1 12.4 0.3 — 86.6 (86.6) 64.8 Other Income, Net 74.6 14.5 21.6 2.2 1,059.6 (1,049.6) 122.9 Income Tax (Expense)/Benefit (103.2) (88.6) (143.5) 2.4 57.1 — (275.8) Net Income 352.3 253.7 409.0 17.9 924.0 (1,049.6) 907.3 Net Income Attributable to Noncontrolling Interests (2.3) — (1.5) — — — (3.8) Net Income Attributable to Common Shareholders $ 350.0 $ 253.7 $ 407.5 $ 17.9 $ 924.0 $ (1,049.6) $ 903.5 Cash Flows Used for Investments in Plant $ 983.2 $ 372.5 $ 505.7 $ 68.1 $ 119.9 $ — $ 2,049.4 (1) The significant expense categories and amounts align with the segment-level information that is regularly provided to the chief operating decision maker. Costs of the operations organization include labor and overtime, outside services, vehicles, vegetation management, employee expenses, fees and payments, regulatory assessments, and materials, partially offset by reimbursements. Corporate shared services include corporate centralized functions. Costs within these corporate functions primarily include labor, services by vendors, fees and payments, insurance, and regulatory assessments. Other includes information technology system depreciation at Eversource Service charged to the operating businesses, as well as storm funding, capitalization and various other corporate costs. The segment-level operating expense for information technology system depreciation is eliminated and reflected in depreciation in Eversource’s consolidation. For the water distribution segment, the chief operating decision maker is provided with total operations and maintenance expense information to manage its operations. Operations and maintenance expenses primarily include employee costs, benefits, and outside services. (2) Other segment line items for the electric distribution, electric transmission and natural gas distribution segments primarily include purchased power, purchased natural gas and transmission, taxes other than income taxes including property, payroll-related and Connecticut gross earnings taxes, and energy efficiency program expenses. Other segment line items for the water distribution business primarily include taxes other than income taxes. The following table summarizes Eversource's segmented total assets: Eversource(Millions of Dollars) Electric Distribution Natural Gas Distribution Electric Transmission Water Distribution Other Eliminations Total As of June 30, 2026 $ 35,435.5 $ 10,725.6 $ 17,562.6 $ — $ 29,851.4 $ (30,159.4) $ 63,415.7 As of December 31, 2025 34,858.1 10,865.5 17,193.9 2,977.6 29,743.3 (31,851.7) 63,786.7 17. SALE OF AQUARION WATER DISTRIBUTION BUSINESS On January 27, 2025, Eversource entered into a definitive agreement to sell Aquarion to the Aquarion Water Authority (AWA), a quasi-public corporation and political subdivision of the State of Connecticut and a standalone, newly created water authority alongside the South Central Connecticut Regional Water Authority. In June 2024, a Connecticut law chartered AWA and enabled it to acquire, own, and operate Aquarion as a not-for-profit water authority. The sale was approved by PURA on March 25, 2026. On June 30, 2026, Eversource completed the sale of Aquarion consistent with all regulatory terms and requirements. The total transaction purchase price was approximately $2.4 billion, which included approximately $650 million of long-term debt that was either repaid at closing or transferred to the buyer. The adjusted net equity proceeds of approximately $1.7 billion will be used to reduce Eversource parent debt. As a result of the sale, Eversource recognized a non-cash, after-tax charge of $111.4 million in the second quarter of 2026, which is presented separately within Operating Expenses on the Eversource statement of income. The carrying value of the water distribution reporting unit included net property, plant and equipment of approximately $2.0 billion and goodwill of $662.4 million that was derecognized upon sale. As conditions of PURA’s approval, Eversource contributed $10 million into a rate stabilization fund for the future benefit of Aquarion customers and returned to 40 customers $5.8 million of revenues collected and held in escrow related to the 2022 rate case appeal. Additional transaction costs resulting from the sale were $29 million. The assets and liabilities associated with the sale of the water distribution business were previously reflected in the Water Distribution segment and reporting unit. Eversource has no post-closing obligations under the purchase and sale agreement with AWA other than a working capital true-up to the purchase price and no continued involvement with the divested subsidiaries. For the three months ended June 30, 2026 and 2025, pre-tax income associated with the water distribution business (excluding the $111.4 million charge) was $10.0 million and $13.0 million, respectively. For the six months ended June 30, 2026 and 2025, pre-tax income associated with the water distribution business (excluding the $111.4 million charge) was $16.0 million and $15.5 million, respectively. 41 EVERSOURCE ENERGY AND SUBSIDIARIES Management's Discussion and Analysis of Financial Condition and Results of Operations The following discussion and analysis should be read in conjunction with our unaudited condensed consolidated financial statements and related combined notes included in this combined Quarterly Report on Form 10-Q, the combined Quarterly Report on Form 10-Q for the quarter ended March 31, 2026, as well as the Eversource 2025 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 2026 earnings and EPS excluding a charge on the sale of the Aquarion water distribution business, a charge associated with increasing our offshore wind contingent liability, and a charge related to the March 2026 FERC decision in the FERC base ROE complaints. 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 charge on the sale of the Aquarion water distribution business, the charge associated with increasing our offshore wind contingent liability, and the charge related to the March 2026 FERC decision in the FERC base ROE complaints 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 indicators 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 do not provide a reconciliation of guidance from non-GAAP recurring earnings or non-GAAP recurring EPS to the most directly comparable GAAP measures because we are not able to predict with reasonable certainty the amount or nature of all items that will be included in our Net Income Attributable to Common Shareholders or EPS for the year ending December 31, 2026. These items are uncertain, depend on many factors and could have a material impact on our Net Income Attributable to Common Shareholders and EPS for the year ending December 31, 2026, and therefore cannot be made available without unreasonable effort. 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 U.S. federal securities laws. You can generally identify our forward-looking statements through the use of words or phrases such as "estimate," "expect," "pending," "anticipate," "intend," "plan," "project," "believe," "forecast," "would," "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: • cyber events or breaches, including acts of war or terrorism, affecting our systems or the systems of third parties on which we rely, •unauthorized access to, and the misappropriation of, confidential and proprietary Company, customer, employee, financial or system operating information, •actions or inaction of local, state and federal regulatory, public policy and taxing bodies, •changes in laws, regulations, Presidential executive orders or regulatory policy, including compliance with laws and regulations, which may impact the cost of compliance and strategic initiatives of the Company, •adverse publicity, which can harm our reputation, influence legislative and regulatory bodies, and result in unfavorable outcomes, •variability in the costs and final investment returns of the Revolution Wind and South Fork Wind offshore wind projects as it relates to the purchase price post-closing adjustment under the terms of the sale agreement for these projects, •the ability to qualify for investment tax credits, •extreme weather, including severe storms, due to the impacts of climate change, and fluctuations in weather patterns, •physical attacks or grid disturbances that may damage and disrupt our electric transmission and electric and natural gas distribution systems, •ability or inability to commence and complete our major strategic development projects and opportunities, •breakdown, failure of, or damage to operating equipment, information technology systems, or processes of our transmission and distribution systems, 42 •changes in levels or timing of capital expenditures, including unplanned expenditures and increased capital expenditure requirements, •changes in business conditions, which could include disruptive technology or development of alternative energy sources related to our current or future business model, •substandard performance of third-party suppliers and service providers, or counterparties not meeting their obligations, •limits on our access to, or increases in, the cost of capital, including 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, tariffs and customer demand and payment ability, •changes in accounting standards and financial reporting regulations, •actions of rating agencies, and •other presently unknown or unforeseen factors. Other risk factors are detailed in our reports filed with the SEC and are updated as necessary and available on our Investor Relations website at investors.eversource.com and on the SEC’s website at www.sec.gov, 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 2025 combined Annual Report on Form 10-K. This combined Quarterly Report on Form 10-Q and Eversource's 2025 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) and Yankee Gas, NSTAR Gas and EGMA (natural gas utilities). On June 30, 2026, Eversource completed the sale of the Aquarion water distribution business, which comprised its water distribution reportable segment. Eversource is organized into the electric distribution, electric transmission, and natural gas distribution reportable segments, and the water distribution reportable segment until the Aquarion sale. 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 $53.7 million, or $0.14 per share, in the second quarter of 2026, compared with $352.7 million, or $0.96 per share, in the second quarter of 2025. We earned $660.5 million, or $1.75 per share, in the first half of 2026, compared with $903.5 million, or $2.45 per share, in the first half of 2025. •Our second quarter of 2026 and first half of 2026 results include a non-cash, after-tax charge of $111.4 million, or $0.30 per share, resulting from a loss on the June 30, 2026 sale of Aquarion, which was recorded within the Water Distribution segment. Those results also include an after-tax charge of $164.0 million, or $0.43 per share, resulting from increasing our offshore wind contingent liability for expected future payments under a 2024 sale agreement of our previous offshore wind investments. This charge was recorded within Eversource Parent and Other Companies. Our first half of 2026 results also include an after-tax charge of $43.9 million, or $0.12 per share, for estimated refunds resulting from FERC’s March 19, 2026 order in the NETO ROE complaint proceedings, which was recorded within the Transmission segment. Excluding these charges, our non-GAAP earnings were $329.1 million, or $0.87 per share, in the second quarter of 2026 and $979.8 million, or $2.60 per share, in the first half of 2026. •We reaffirmed our projection to earn within a 2026 non-GAAP recurring earnings guidance range of between $4.57 per share and $4.72 per share, which includes the impact of the prospective reduction to the transmission ROE resulting from the March 19, 2026 FERC order and the absence of Aquarion earnings in the second half of the year. We also reaffirmed that our cumulative long-term earnings per share growth rate will be within the range of 5 to 7 percent through 2030, using the adjusted 2026 non-GAAP earnings guidance mid-point of $4.65 per share as the base year. We expect annual earnings growth towards the upper half of the long-term guidance by 2028. Liquidity: •Cash flows provided by operating activities totaled $2.41 billion in the first half of 2026, compared with $2.10 billion in the first half of 2025. Investments in property, plant and equipment totaled $2.02 billion in the first half of 2026, compared with $2.05 billion in the first half of 2025. 43 •Cash and Cash Equivalents totaled $1.82 billion as of June 30, 2026, compared with $135.4 million as of December 31, 2025. Our available borrowing capacity under our commercial paper programs totaled $2.16 billion as of June 30, 2026. •In the first half of 2026, we issued $2.40 billion of new long-term debt and we repaid $1.62 billion of long-term debt. •On May 6, 2026, our Board of Trustees approved a common share dividend payment of $0.7875 per share, payable on June 30, 2026 to shareholders of record as of May 18, 2026. Regulatory Developments: •On June 30, 2026, Eversource completed the sale of Aquarion consistent with all regulatory terms and requirements. The total transaction purchase price was approximately $2.4 billion, which included approximately $650 million of long-term debt that was either repaid at closing or transferred to the buyer. The adjusted net equity proceeds of approximately $1.7 billion will be used to reduce Eversource parent debt. As a result of the sale, Eversource recognized a non-cash, non-recurring charge, after-tax charge of $111.4 million in the second quarter of 2026. •On July 14, 2026, CL&P filed an application with PURA to request an increase in base distribution rates to provide additional revenues of approximately $451 million annually, exclusive of the impact of catastrophic storms and pre‑staging events occurring between January 2018 and March 2025. As part of the rate case, CL&P proposes to implement a performance-based multi-year rate plan that would adjust rates annually over a four-year term from July 1, 2027 through June 30, 2031, with a corresponding stay out provision. The plan includes a revenue-cap formula adjusted for inflation, a supplemental capital adjustment formula to support CL&P’s planned capital infrastructure improvements, an exogenous events recovery mechanism, performance metrics and an earnings sharing mechanism, among other proposals. The proposed revenue requirement includes a regulatory return on equity of 10.25 percent with a 53.86 percent common equity ratio for CL&P’s capital structure. A decision by PURA is expected by June 29, 2027. •On July 29, 2026, PURA issued a final decision on CL&P’s request for recovery of deferred storm costs totaling $974.2 million plus carrying costs. PURA approved the vast majority of requested storm costs totaling $869.4 million of catastrophic storms and pre‑staging events occurring between January 1, 2018 and December 31, 2023 and postponed review of $63.3 million of storm costs to a future proceeding. The final decision also authorized the accrual of carrying costs on unrecovered, approved storm costs beginning on the date of the final decision. CL&P is currently evaluating the impact of costs not allowed for recovery in the decision and potential legal courses of action. The impact of the decision will be recorded in the third quarter of 2026. Earnings Overview Consolidated: Below is a summary of our earnings by business, which also reconciles the non-GAAP financial measures of consolidated non-GAAP earnings and EPS, as well as EPS by business, to the most directly comparable GAAP measures of consolidated Net Income Attributable to Common Shareholders and diluted EPS. For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (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) $ 53.7 $ 0.14 $ 352.7 $ 0.96 $ 660.5 $ 1.75 $ 903.5 $ 2.45 Regulated Companies (Non-GAAP) $ 395.4 $ 1.05 $ 419.2 $ 1.14 $ 1,124.1 $ 2.98 $ 1,029.1 $ 2.79 Eversource Parent and Other Companies (Non-GAAP) (66.3) (0.18) (66.5) (0.18) (144.3) (0.38) (125.6) (0.34) Non-GAAP Earnings $ 329.1 $ 0.87 $ 352.7 $ 0.96 $ 979.8 $ 2.60 $ 903.5 $ 2.45 Sale of Aquarion (after-tax) (1) (111.4) (0.30) — — (111.4) (0.30) — — Loss on Offshore Wind (after-tax) (2) (164.0) (0.43) — — (164.0) (0.43) — — FERC ROE Refund Charge (after-tax) (3) — — — — (43.9) (0.12) — — Net Income Attributable to Common Shareholders (GAAP) $ 53.7 $ 0.14 $ 352.7 $ 0.96 $ 660.5 $ 1.75 $ 903.5 $ 2.45 (1) In the second quarter of 2026, we recorded a non-cash, after-tax charge of $111.4 million resulting from the loss on the June 30, 2026 sale of Aquarion. For further information, see the “Business Development and Capital Expenditures - Sale of Aquarion Water Distribution Business” section included in this Management’s Discussion and Analysis of Financial Condition and Results of Operations. (2) In the second quarter of 2026, we recorded a pre-tax charge of $194 million ($164 million after-tax) associated with increasing our offshore wind contingent liability for expected future payments under the terms of the 2024 sale agreement with GIP for the Revolution Wind project. For further information, see the “Offshore Wind Contingent Liability” section below included in this Management’s Discussion and Analysis of Financial Condition and Results of Operations. (3) In the first half of 2026, we recorded a pre-tax charge of $60.4 million ($43.9 million after-tax) as a result of the March 19, 2026 FERC decision in the FERC base ROE complaints. The charge reflects a liability recorded for refunds associated with the fifteen-month first complaint period (October 1, 2011 – December 31, 2012), including interest accrued from the refund period through March 31, 2026. For 44 further information, see the “FERC Regulatory Matters” section included in this Management’s Discussion and Analysis of Financial Condition and Results of Operations. The impact of higher shares outstanding resulted in $0.04 earnings per share dilution in the first half of 2026, as compared to the first half of 2025. Regulated Companies: Our regulated companies comprise the electric distribution, electric transmission, natural gas distribution, and water distribution segments. A summary of our segment earnings and EPS is as follows: For the Three Months Ended June 30, For the Six Months Ended June 30, 2026 2025 2026 2025 (Millions of Dollars, Except Per Share Amounts) Amount Per Share Amount Per Share Amount Per Share Amount Per Share Net Income - Regulated Companies (GAAP) $ 284.0 $ 0.75 $ 419.2 $ 1.14 $ 968.8 $ 2.56 $ 1,029.1 $ 2.79 Electric Distribution $ 170.4 $ 0.45 $ 161.5 $ 0.44 $ 373.1 $ 0.99 $ 350.0 $ 0.95 Electric Transmission, excluding FERC ROE Refund Charge (Non-GAAP) 183.7 0.49 208.0 0.56 408.0 1.08 407.5 1.11 Natural Gas Distribution 29.7 0.08 35.3 0.10 325.1 0.86 253.7 0.68 Water Distribution, excluding Sale of Aquarion (Non-GAAP) 11.6 0.03 14.4 0.04 17.9 0.05 17.9 0.05 Net Income - Regulated Companies (Non-GAAP) $ 395.4 $ 1.05 $ 419.2 $ 1.14 $ 1,124.1 $ 2.98 $ 1,029.1 $ 2.79 Sale of Aquarion (after-tax) (111.4) (0.30) — — (111.4) (0.30) — — FERC ROE Refund Charge (after-tax) — — — — (43.9) (0.12) — — Net Income - Regulated Companies (GAAP) $ 284.0 $ 0.75 $ 419.2 $ 1.14 $ 968.8 $ 2.56 $ 1,029.1 $ 2.79 Our electric distribution segment earnings increased $8.9 million and $23.1 million in the second quarter and the first half of 2026, respectively, as compared to the second quarter and the first half of 2025, due primarily to higher revenues from base distribution rate increases at NSTAR Electric effective January 1, 2026 and at PSNH effective August 1, 2025, and higher revenues from CL&P’s capital tracking mechanism due to increased electric system improvements and NSTAR Electric’s Advanced Metering Infrastructure (AMI) capital tracking mechanism. These benefits were partially offset by higher interest expense, higher depreciation and higher property taxes. Our electric transmission segment earnings decreased $24.3 million in the second quarter of 2026, as compared to the second quarter of 2025, due primarily to the prospective impact from the March 19, 2026 FERC decision in the FERC base ROE complaints that lowered the allowed ROE from 10.57 percent to 9.57 percent, as well as higher interest expense, partially offset by continued investment in our transmission infrastructure. Our electric transmission segment earnings decreased $43.4 million in the first half of 2026, as compared to the first half of 2025, due primarily to the first quarter 2026 after-tax charge of $43.9 million resulting from the March 19, 2026 FERC decision in the FERC base ROE complaints in which the Company recorded a liability for refunds for the fifteen-month first complaint period, including interest. Excluding this charge, our electric transmission segment earnings increased $0.5 million in the first half of 2026, as compared to the first half of 2025, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure and higher non-refundable transmission revenues, partially offset by the impact of the decrease in the allowed ROE from 10.57 percent to 9.57 percent and higher interest expense. Our natural gas distribution segment earnings decreased $5.6 million in the second quarter of 2026, as compared to the second quarter of 2025, due primarily to the absence of a benefit in 2025 from previously expensed costs allowed for recovery, higher depreciation and higher property taxes, partially offset by higher revenues from the base distribution rate increase effective November 1, 2025 at Yankee Gas and from capital tracking mechanisms due to continued investments in natural gas infrastructure. Our natural gas distribution segment earnings increased $71.4 million in the first half of 2026, as compared to the first half of 2025, due primarily to higher revenues from base distribution rate increases effective November 1, 2025 at Yankee Gas, NSTAR Gas and EGMA, and from capital tracking mechanisms due to continued investments in natural gas infrastructure. Those earnings increases were partially offset by higher operations and maintenance expense, higher depreciation, the absence of a benefit in 2025 from previously expensed costs allowed for recovery, higher property taxes, a higher effective income tax rate, and higher interest expense. Our water distribution segment earnings decreased $114.2 million and $111.4 million in the second quarter and the first half of 2026, respectively, as compared to the second quarter and the first half of 2025, due primarily to the $111.4 million after-tax charge on the sale of Aquarion. Excluding this charge, our water distribution segment earnings decreased $2.8 million in the second quarter of 2026, as compared to the second quarter of 2025, due primarily to higher operations and maintenance expense and higher depreciation, partially offset by higher revenues. Excluding this charge, water distribution segment earnings remained flat in the first half of 2026, as compared to the first half of 2025. For further information on the sale, see the “Business Development and Capital Expenditures - Sale of Aquarion Water Distribution Business” section included in this Management’s Discussion and Analysis of Financial Condition and Results of Operations. Eversource Parent and Other Companies: Eversource parent and other companies losses increased by $163.8 million and $182.7 million in the second quarter and the first half of 2026, respectively, as compared to the second quarter and the first half of 2025, due primarily to the after-tax charge of $164.0 million resulting from an increase to the offshore wind contingent liability. Excluding this charge, Eversource parent and other companies losses decreased by $0.2 million in the second quarter of 2026, as compared to the second quarter of 2025, and increased by $18.7 45 million in the first half of 2026, as compared to the first half of 2025. Results in both periods were driven by higher interest expense and a higher effective income tax rate. Offshore Wind Contingent Liability: On September, 30, 2024, Eversource completed the sale of its 50 percent ownership share in the South Fork Wind and Revolution Wind Projects to Global Infrastructure Partners (GIP). Eversource recorded a contingent liability relating to expected future payments to GIP as part of the sale of the South Fork Wind and Revolution Wind projects. As part of the definitive agreement with GIP, Eversource is responsible for certain post-closing purchase price adjustments. This obligation included an expected cost overrun sharing obligation, an expected obligation to maintain GIP’s internal rate of return, and an obligation for other future costs. In the second quarter of 2026, Eversource received revised projections of total construction costs associated with Revolution Wind, which included quantifiable cost increases. As a result, Eversource recognized a pre-tax charge of $194 million in the second quarter of 2026 to increase the liability for purchase price adjustments associated with the Revolution Wind project. Payments made in the first half of 2026 and 2025 of $233.0 million and $68.6 million, respectively, reduced the contingent liability and were reflected within investing activities on the statement of cash flows. Payments made in 2026 related to cost overruns for the Revolution Wind project paid to GIP and payment in 2025 related to a purchase price adjustment payment for the South Fork Wind project paid to GIP. Eversource continually evaluates the contingent liability and will reassess the balance as new information becomes available. Based on most recent updates on the construction status of Revolution Wind and other information currently available, Eversource believes that the contingent liability balance as of June 30, 2026 is an adequate estimate to cover this contingent liability for purchase price adjustments. As of June 30, 2026 and December 31, 2025, the contingent liability totaled $409.2 million and $448.2 million, respectively, and is recorded as a current liability on Eversource’s balance sheets, based upon the timing of expected payments to GIP. Eversource relies on information that it receives from the project owners for the construction-related, delay-related, and insurance-related costs of Revolution Wind. Eversource uses its judgment to adjust, as needed, its expected obligations to GIP while construction of Revolution Wind is completed. New information or future developments that arise as the construction of Revolution Wind progresses will necessitate a reassessment of the estimated liability to GIP. The Company reviews available projections of total construction costs, including the latest cost estimates and project timeline, to determine if any changes to this liability are warranted. It is reasonably possible that as additional updated cost estimates become available, and if additional cost overruns materialize or other adverse changes in facts, regulations and circumstances occur, there could be additional losses and increases to the offshore wind contingent liability, which could be material. The Company will continue to monitor developments and evaluate potential exposures related to this contingency and will revise its estimated liability as additional information becomes available. Contingencies are evaluated using the best information available at the time the financial statements are published, and this assessment involves judgments and assumptions about future events. Factors that could increase the obligation to GIP include construction cost overruns for Revolution Wind as well as the timing and extent of construction delays, which would impact the economics associated with the purchase price adjustment, and the eligibility for federal investment tax credits for Revolution Wind at a value lower than assumed and included in the purchase price. The purchase price of Revolution Wind included the sales value related to a 40 percent level of federal investment tax credits. A change in the expected value or qualification of investment tax credit adders could result in a significant loss in a future period. Total net proceeds could also be adjusted for a benefit due to Eversource if there are lower operation costs or higher availability of the projects through the period that is four years following the commercial operation of Revolution Wind. 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 corporate obligations. 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 including 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. 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. 46 Cash and Cash Equivalents totaled $1.82 billion as of June 30, 2026, compared with $135.4 million as of December 31, 2025. The June 30, 2026 Cash and Cash Equivalents balance includes approximately $1.7 billion of net proceeds received from the June 30, 2026 sale of Aquarion. The Company expects to utilize the net proceeds to reduce Eversource parent 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 and EGMA are parties to a five-year $2.00 billion revolving credit facility. Effective October 11, 2025, the revolving credit facility’s termination date was extended for one additional year to October 11, 2030, pursuant to the extension provisions contained in the existing credit agreement. 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. Effective October 11, 2025, the revolving credit facility’s termination date was extended for one additional year to October 11, 2030, pursuant to the extension provisions contained in the existing credit agreement. This revolving credit facility serves to backstop NSTAR Electric's $650 million commercial paper program. The amount of borrowings outstanding and available under the commercial paper programs were as follows: Borrowings Outstanding as of Available Borrowing Capacity as of Weighted-Average Interest Rate as of June 30, 2026 December 31, 2025 June 30, 2026 December 31, 2025 June 30, 2026 December 31, 2025 (Millions of Dollars) Eversource Parent Commercial Paper Program $ 432.0 $ 1,280.0 $ 1,568.0 $ 720.0 4.00 % 3.98 % NSTAR Electric Commercial Paper Program 63.0 245.4 587.0 404.6 3.87 % 3.87 % There were no borrowings outstanding on the revolving credit facilities as of June 30, 2026 and December 31, 2025. CL&P and PSNH have uncommitted line of credit agreements totaling $375 million and $250 million, respectively, all of which will expire in either September 2026, October 2026 or May 2027. There are no borrowings outstanding on either the CL&P or PSNH uncommitted line of credit agreements as of June 30, 2026 and December 31, 2025. Amounts outstanding under the commercial paper programs are included in Notes Payable and classified in current liabilities on the Eversource and NSTAR Electric balance sheets, as all borrowings are outstanding for no more than 364 days at one time. As a result of the Yankee Gas long-term debt issuances on July 15, 2026, $62.3 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2026. As a result of the EGMA long-term debt issuances on July 15, 2026, $39.0 million of commercial paper borrowings under the Eversource parent commercial paper program were reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2026. Intercompany Borrowings: Eversource parent uses its available capital resources to provide loans to its subsidiaries to assist in meeting their short-term borrowing needs. Eversource parent records intercompany interest income from its loans to subsidiaries, which is eliminated in consolidation. Intercompany loans from Eversource parent to its subsidiaries are eliminated in consolidation on Eversource's balance sheets. As of June 30, 2026 and December 31, 2025, there were intercompany loans from Eversource parent to PSNH of $2.1 million and $49.3 million, respectively. As of June 30, 2026, there were intercompany loans from Eversource parent to CL&P of $107.0 million. Eversource parent charges interest on these intercompany loans at the same weighted-average interest rate as its commercial paper program. Intercompany loans from Eversource parent are included in Notes Payable to Eversource Parent and classified in current liabilities on the respective subsidiary's balance sheets, as these intercompany borrowings are outstanding for no more than 364 days at one time. Long-Term Debt Issuance Authorizations: On March 3, 2026, PSNH filed a petition with the NHPUC requesting authorization to issue up to $200.0 million in long-term debt through December 31, 2026. PSNH has utilized its long-term debt authorizations in place with the NHPUC. On July 17, 2026, NSTAR Electric filed a petition with the DPU requesting authorization to issue up to $3.2 billion in long-term debt through December 31, 2029. 47 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 NSTAR Electric Debentures 4.65 % $ 350.0 May 2026 May 2031 Repaid 2.70% Debentures at maturity, repaid Series H Senior Notes at maturity, repaid short-term debt, paid capital expenditures and working capital NSTAR Electric Debentures 5.20 % 350.0 May 2026 May 2036 Repaid 2.70% Debentures at maturity, repaid Series H Senior Notes at maturity, repaid short-term debt, paid capital expenditures and working capital NSTAR Electric Debentures 2.70 % (250.0) June 2026 June 2026 Paid at maturity NSTAR Electric Series H Senior Notes 2.75 % (50.0) June 2026 June 2026 Paid at maturity PSNH Series X First Mortgage Bonds 5.35 % 200.0 June 2026 October 2033 Repaid short-term debt, paid capital expenditures and working capital Eversource Parent Series A Junior Notes (1) 6.10 % 750.0 February 2026 August 2056 Repaid Series AA Senior Notes at maturity, repay Series U Senior Notes at maturity, repaid short-term debt, and for general corporate purposes Eversource Parent Series B Junior Notes (2) 6.35 % 750.0 February 2026 August 2056 Repaid Series AA Senior Notes at maturity, repay Series U Senior Notes at maturity, repaid short-term debt, and for general corporate purposes Eversource Parent Series J Senior Notes 3.35 % (250.0) March 2026 March 2026 Paid at maturity Eversource Parent Series AA Senior Notes 4.75 % (450.0) May 2026 May 2026 Paid at maturity Yankee Gas Series AA First Mortgage Bonds 5.22 % 75.0 July 2026 July 2031 Refinance existing indebtedness, fund capital expenditures, and for general corporate purposes Yankee Gas Series BB First Mortgage Bonds 5.61 % 100.0 July 2026 July 2036 Refinance existing indebtedness, fund capital expenditures, and for general corporate purposes EGMA Series G First Mortgage Bonds 5.12 % 100.0 July 2026 July 2031 Refinance existing indebtedness, fund capital expenditures, and for general corporate purposes (1) The Eversource Parent Series A Junior Subordinated Notes bear interest at a fixed rate of 6.10 percent per year from the issuance date of February 26, 2026 to August 14, 2031. Thereafter, the interest rate resets every five years, commencing on August 15, 2031, at a rate per year equal to the five-year U.S. Treasury Rate plus a spread of 2.521 percent. (2) The Eversource Parent Series B Junior Subordinated Notes bear interest at a fixed rate of 6.35 percent per year from the issuance date of February 26, 2026 to August 14, 2036. Thereafter, the interest rate resets every five years, commencing on August 15, 2036, at a rate per year equal to the five-year U.S. Treasury Rate plus a spread of 2.325 percent. In connection with the sale of Aquarion on June 30, 2026, $612.4 million of long-term debt was repaid at closing. As a result of the Yankee Gas long-term debt issuances on July 15, 2026, $90.0 million of current portion of long-term debt was reclassified to Long-Term Debt on Eversource parent’s balance sheet as of June 30, 2026. Rate Reduction Bonds: PSNH's RRB payments consist of principal and interest and are paid semi-annually. PSNH paid $21.6 million of RRB principal payments and $6.1 million of interest payments in the first half of 2026, and paid $21.6 million of RRB principal payments and $6.9 million of interest payments in the first half of 2025. Common Share Issuances and Equity Distribution Agreement: On May 30, 2025, Eversource entered into an equity distribution agreement pursuant to which it may offer and sell up to $1.2 billion of its common shares from time to time through an ATM equity offering program. In 2025, we issued 7,130,134 common shares, which resulted in proceeds of $465.4 million, net of issuance costs. In the second quarter of 2026, Eversource issued 289,044 common shares, which resulted in proceeds of $20.2 million, net of issuance costs. Eversource used the net proceeds received for general corporate purposes. Cash Flows: Cash flows from operating activities primarily result from the transmission and distribution of electricity, and the distribution of natural gas. Cash flows provided by operating activities totaled $2.41 billion in the first half of 2026, compared with $2.10 billion in the first half of 2025. Operating cash flows were favorably impacted by the timing of cash collections on our accounts receivable, an improvement in regulatory recoveries for retail and wholesale transmission costs and natural gas regulatory cost tracking mechanisms driven by the timing of collections, a $59.0 million decrease in cost of removal expenditures, a $56.7 million increase in income tax refunds received in 2026 compared to 2025, and the timing of other working capital items. These favorable impacts were partially offset by a decrease in regulatory recoveries for CL&P’s non-bypassable FMCC and SBC cost tracking mechanisms driven primarily by the timing of collections, the timing of cash payments made on our accounts payable, and a $13.3 million increase in cash payments to vendors for storm costs. The impacts of regulatory collections are included in both Regulatory Recoveries and Amortization on the statements of cash flows. Additionally, under a winter electric bill relief program in Massachusetts, bill credits were provided to electric and natural gas customers in the first quarter of 2026, which resulted in delayed collections that will be recovered later in 2026, and were partially offset by proceeds of $84.1 million received from the Commonwealth of Massachusetts at NSTAR Electric in January 2026 to fund a portion of the bill relief. 48 On May 6, 2026, our Board of Trustees approved a common share dividend payment of $0.7875 per share, payable on June 30, 2026 to shareholders of record as of May 18, 2026. In the first half of 2026, we paid cash dividends of $580.3 million and issued non-cash dividends of $11.9 million in the form of treasury shares, totaling dividends of $592.2 million. In the first half of 2025, we paid cash dividends of $540.9 million and issued non-cash dividends of $11.8 million in the form of treasury shares, totaling dividends of $552.7 million. Eversource issues treasury shares to satisfy awards under the Company's incentive plans, shares issued under the dividend reinvestment and share purchase plan, and matching contributions under the Eversource 401k Plan. In the first half of 2026, CL&P, NSTAR Electric and PSNH paid $176.8 million, $331.0 million, and $127.9 million, respectively, in common stock dividends to Eversource parent. Investments in Property, Plant and Equipment on the statements of cash flows do not include amounts incurred on capital projects but not yet paid, cost of removal, AFUDC related to equity funds, and the capitalized and deferred portions of pension and PBOP income/expense. In the first half of 2026, investments for Eversource, CL&P, NSTAR Electric, and PSNH were $2.02 billion, $511.5 million, $773.8 million, and $197.4 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. For our offshore wind contingent liability, payments made in the first half of 2026 and 2025 reduced the liability and were reflected within investing activities on the statement of cash flows. Payments made in 2026 related to cost overruns for the Revolution Wind project paid to GIP and payment in 2025 related to a purchase price adjustment payment for the South Fork Wind project paid to GIP. 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 2025 Form 10-K. There have been no material changes to our cash requirements from contractual obligations and payment schedules previously disclosed in our 2025 Form 10-K. Credit Ratings: On July 6, 2026, Moody’s revised the outlook of both Eversource parent and NSTAR Electric from negative to stable due to the closing of the sale of Aquarion and the approval of storm costs in Connecticut. Business Development and Capital Expenditures Our consolidated capital expenditures, including amounts incurred but not paid, cost of removal, AFUDC, and the capitalized and deferred portions of pension and PBOP income/expense (all of which are non-cash factors), totaled $1.97 billion in the first half of 2026, compared to $2.15 billion in the first half of 2025. These amounts included $101.4 million and $104.4 million in the first half of 2026 and 2025, respectively, at Eversource Service and The Rocky River Realty Company primarily for information technology and facilities upgrades. Electric Transmission Business: Our consolidated electric transmission business capital expenditures decreased by $5.6 million in the first half of 2026, as compared to the first half of 2025. A summary of electric transmission capital expenditures by company is as follows: For the Six Months Ended June 30, (Millions of Dollars) 2026 2025 CL&P $ 205.4 $ 159.3 NSTAR Electric 203.7 200.1 PSNH 84.0 139.3 Total Electric Transmission $ 493.1 $ 498.7 Our transmission projects are designed to improve the reliability of the electric grid, meet customer demand for power, and strengthen the electric grid's resilience against extreme weather and other safety and security threats. In Connecticut, Massachusetts and New Hampshire, our transmission projects include transmission line upgrades, the installation of new transmission interconnection facilities, substations and lines, and transmission substation enhancements. Greater Cambridge Energy Program: The Greater Cambridge Energy Program will construct Eversource’s first underground transmission substation in Cambridge, Massachusetts, along with associated transmission and distribution lines. The project will address the increased electric demand in the region, enhance the resiliency of the transmission system, and ensure a flexible grid to reliably serve customers. The flexibility to transmit and distribute mixed energy sources will support the decarbonization and electrification goals of both the City of Cambridge and the state of Massachusetts. The new 115/13.8-kV, 35,000 square foot substation will be located in an underground vault and includes three distribution power transformers supplying thirty-six distribution circuits. The project also includes five underground duct banks housing eight new 115-kV transmission lines. The Massachusetts Energy Facilities Siting Board approved the project on June 28, 2024. Environmental permits are acquired to support ongoing construction activities. Additional required permits for transmission line trenchless crossings, including a license from the MA DEP, are expected to be approved by the end of 2026. The initial in-service date for the project is June 2029, which includes two 115-kV transmission lines and the transmission portion of the substation. The first distribution circuits and substation distribution will be placed in-service by the end of 2029. The remaining transmission and distribution circuits will be placed in-service throughout 2030 and into 2031. The total estimated project cost is approximately $1.84 billion, with $1.38 billion allocated for transmission and $460 million for distribution. As of June 30, 2026, $265.4 million has been spent on the project, with $208.0 million for transmission and $57.4 million for distribution. 49 ISO-NE Longer-Term Transmission Planning RFP: On March 31, 2025, ISO-NE issued the 2025 Longer-Term Transmission Planning Request for Proposal (RFP) to address longer-term needs that the New England States Committee on Electricity (NESCOE) identified in a December 13, 2024 request for ISO-NE to issue a longer-term transmission RFP. Following a full evaluation of the transmission tariff and RFP requirements, on July 22, 2026, ISO-NE selected a joint proposal submitted by Eversource (for NSTAR Electric and PSNH) and Central Maine Power as the preliminary preferred solution. This transmission project is designed to increase transmission capacity between Maine and New Hampshire while strengthening the transmission interface between northern and southern New England and accommodating interconnection of at least 1,200 MW of onshore wind. Eversource’s share of the total estimated $2.2 billion project cost is approximately $700 million and the project has an anticipated in-service date in 2032. After stakeholder input due in August 2026, ISO-NE will select the preferred solution for development and NESCOE will then determine whether to allow the process to proceed. Distribution Business: A summary of distribution capital expenditures is as follows: For the Six Months Ended June 30, (Millions of Dollars) CL&P NSTAR Electric PSNH Total Electric Natural Gas Water Total 2026 Basic Business $ 167.5 $ 288.5 $ 44.1 $ 500.1 $ 87.4 $ 10.2 $ 597.7 Aging Infrastructure 55.8 207.9 41.7 305.4 251.3 70.7 627.4 Load Growth and Other 65.4 63.9 9.0 138.3 14.4 0.4 153.1 Total Distribution $ 288.7 $ 560.3 $ 94.8 $ 943.8 $ 353.1 $ 81.3 $ 1,378.2 2025 Basic Business $ 161.0 $ 266.5 $ 77.7 $ 505.2 $ 100.8 $ 9.6 $ 615.6 Aging Infrastructure 61.7 221.9 48.7 332.3 317.7 63.3 713.3 Load Growth and Other 51.2 115.0 32.5 198.7 21.0 0.4 220.1 Total Distribution $ 273.9 $ 603.4 $ 158.9 $ 1,036.2 $ 439.5 $ 73.3 $ 1,549.0 For the electric distribution business, basic business includes the purchase of meters, tools, vehicles, information technology, transformer replacements, equipment facilities, and the relocation of plant. Aging infrastructure relates to reliability and the replacement of overhead lines, plant substations, underground cable replacement, and equipment failures. Load growth and other includes requests for new business and capacity additions on distribution lines and substation additions and expansions. We are also focused on making strategic AI investments currently in outage discovery, maintenance management and data analytics to better maintain our system and provide value to our customers. 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. Sale of Aquarion Water Distribution Business: On January 27, 2025, Eversource entered into a definitive agreement to sell Aquarion to the Aquarion Water Authority (AWA), a quasi-public corporation and political subdivision of the State of Connecticut and a standalone, newly created water authority alongside the South Central Connecticut Regional Water Authority. In June 2024, a Connecticut law chartered AWA and enabled it to acquire, own, and operate Aquarion as a not-for-profit water authority. The sale was approved by PURA on March 25, 2026. On June 30, 2026, Eversource completed the sale of Aquarion consistent with all regulatory terms and requirements. The total transaction purchase price was approximately $2.4 billion, which included approximately $650 million of long-term debt that was either repaid at closing or transferred to the buyer. The adjusted net equity proceeds of approximately $1.7 billion will be used to reduce Eversource parent debt. As a result of the sale, Eversource recognized a non-cash, after-tax charge of $111.4 million in the second quarter of 2026, which is presented separately within Operating Expenses on the Eversource statement of income. The carrying value of the water distribution reporting unit included net property, plant and equipment of approximately $2.0 billion and goodwill of $662.4 million that was derecognized upon sale. As conditions of PURA’s approval, Eversource contributed $10 million into a rate stabilization fund for the future benefit of Aquarion customers and returned to customers $5.8 million of revenues collected and held in escrow related to the 2022 rate case appeal. Additional transaction costs resulting from the sale were $29 million. The assets and liabilities associated with the sale of the water distribution business were previously reflected in the Water Distribution segment and reporting unit. Eversource has no post-closing obligations under the purchase and sale agreement with AWA other than a working capital true-up to the purchase price and no continued involvement with the divested subsidiaries. 50 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 New England Transmission Owners’ (NETOs’) base return on equity (ROE) of 11.14 percent that had been utilized since 2006 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 including transmission incentives (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. The NETOs filed an appeal of this decision, which was vacated on April 14, 2017 by the U.S. Court of Appeals for the D.C. Circuit (D.C. Circuit Court). All amounts associated with Opinion No. 531-A on the first complaint period lowering the base ROE of 11.14 percent to 10.57 percent were refunded by 2015. On October 16, 2018, FERC issued an order on all four complaints describing how it intended to address the issues that were remanded by the D.C. Circuit Court. FERC proposed a new framework to determine (1) whether an existing ROE is unjust and unreasonable and, if so, (2) how to calculate a replacement ROE. The 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, the preliminary just and reasonable base ROE for the NETOs, which FERC concludes are of average financial risk, is 10.41 percent and the preliminary incentive cap on total ROE is 13.08 percent. On March 19, 2026, FERC issued Opinion No. 594 in the NETO ROE proceedings, attempting to resolve all four pending complaints dating back to 2011 and respond to the D.C. Circuit Court’s April 14, 2017 decision vacating FERC’s prior decision in the first complaint, which found that the FERC had failed to (1) make an explicit, reasoned finding that the then-existing 11.14 percent base ROE was unjust and unreasonable before imposing a replacement ROE, and (2) adequately justify placing the ROE at the midpoint of the upper half of the zone of reasonableness. In Opinion No. 594, FERC applied a revised ROE methodology that it believes is consistent with its 2024 ROE Order on remand to the Midcontinent ISO (MISO) transmission owners, to satisfy the first step in the FERC process to revise the ROE in a Section 206 proceeding by finding the NETOs’ base ROE of 11.14 percent is unjust and unreasonable. FERC then found the just and reasonable replacement base ROE to be 9.57 percent with an incentive cap of 12.09 percent for the first complaint period (October 1, 2011 – December 31, 2012) and applied this same ROE prospectively, effective October 16, 2014, the date of the first complaint order vacated by the D.C. Circuit Court. FERC directed the NETOs to issue refunds with interest for the applicable refund periods. This decision decreases the allowed base ROE of 10.57 percent with an incentive cap of 11.74 percent to a base ROE of 9.57 percent with an incentive cap of 12.09 percent. The second, third and fourth NETO ROE complaints were dismissed as part of the decision, and FERC did not direct any refunds for the periods associated with those proceedings. On April 14, 2026, FERC granted an extension of the refund deadline to May 20, 2027. On April 14, 2026, Eversource and Avangrid filed a joint motion requesting a stay of the retroactive refund obligation applicable to the period October 16, 2014 through March 19, 2026 (retroactive refund period) with the D.C. Circuit Court. On April 20, 2026, the NETOs submitted to FERC a request for rehearing of Opinion No. 594 highlighting several deficiencies including but not limited to the unlawful retroactive refund period with interest extended beyond the 15-month statutory relief authority granted in Section 206(b) of the Federal Power Act, the FERC not proving that the previously approved 11.14 percent base ROE was unjust and unreasonable as remanded by the D.C. Circuit Court, the flawed methodologies applied in setting the replacement 9.57 percent base ROE, failing to comply with the requirement for FERC to use data that is relevant to the current period at the time of the decision for the NETOs’ prospective ROE, and procedural issues related to overlapping complaints. On May 21, 2026, FERC issued an order denying the request for rehearing by operation of law. The NETOs filed an appeal of Opinion No. 594 and the FERC denial of rehearing by operation of law with the D.C. Circuit Court on June 5, 2026. On April 30, 2026, the NETOs submitted a Federal Power Act Section 205 filing to FERC, which is a formal request by a public utility to change the ROE rate prospectively and requires the utility to prove the proposed change is just and reasonable. The NETOs proposed a replacement base ROE of 11.39 percent, resulting in an incentive cap of 12.89 percent, which is based on current market data utilizing FERC’s ROE methodology from Opinion No. 594. The NETOs requested an effective date of June 30, 2026. On June 29, 2026, FERC issued an order finding the proposed ROE has not been shown to be just and reasonable, suspending the increase until November 30, 2026, subject to refund, and initiating paper hearing procedures. Initial briefs are due in the paper hearing on August 28, 2026, with reply briefs due on September 28, 2026. As a result of the March 19, 2026 FERC decision, Eversource has determined that a refund is probable and that a range of refunds is reasonably estimable. Based on Eversource’s current evaluation of the relevant facts and circumstances, the Company has estimated a range of reasonably possible pre-tax refunds of $62.0 million to $968.4 million, which includes a range of interest of $30.1 million to $271.5 million, as of June 30, 2026. The low end of the estimated range of refunds reflects estimated refunds associated with the fifteen-month first complaint period, including interest. The high end of the estimated range of refunds includes the refunds associated with the first complaint period, as well as estimated refunds for the retroactive refund period from October 16, 2014 through March 19, 2026, including interest, in the pre-tax amount of approximately $906.4 million. The range of refund estimates use the 9.57 percent replacement ROE and incentive cap of 12.09 percent prescribed in the March 19, 2026 FERC decision. Based on Eversource’s legal assessment of the Federal Power Act and the legal and regulatory deficiencies underlying this decision as identified in the rehearing request, including that the retroactive application is inconsistent with the statutory limitations 51 under the Federal Power Act, Eversource does not believe that refunds at the high end of the range for the retroactive period are probable. Eversource continues to challenge the March 19, 2026 FERC decision, but cannot predict the ultimate outcome of these proceedings. The Company has recorded a current regulatory liability for revenues subject to refund of $62.0 million (pre-tax) as of June 30, 2026, which represents the low end of the range, as no amount within this range is considered a better estimate. The regulatory liability recorded reflects the difference between the billed 10.57 percent base ROE and the new 9.57 percent base ROE for the first complaint period, including interest. The liability consists of $29.8 million, $24.6 million and $7.6 million for CL&P, NSTAR Electric and PSNH, respectively, of which $14.4 million, $12.0 million and $3.7 million is accrued interest, respectively, as of June 30, 2026. The revenues subject to refund were recorded as a reduction to Operating Revenues, and the accrued interest was recorded as an increase to Interest Expense in the statements of income. Eversource does not have any other reserves recorded for the other complaint periods, as these remaining complaints were dismissed. The Company’s estimates are based on currently available information; however, it is reasonably possible that the ultimate resolution of this matter may result in a refund in excess of the amount accrued, and such additional losses could have a material impact on the financial condition, results of operations, and cash flows in a future period. The reduction in the base ROE from 10.57 percent to 9.57 percent is expected to lower Eversource's future annual after-tax earnings by approximately $70 million, estimated using 2025 rate base, and excluding the new base ROE of 11.39 percent that will become effective on November 30, 2026, subject to the outcome of the FERC-ordered paper hearing. The impact to earnings would increase over time as we continue to invest in our transmission infrastructure. The change in the related specific transmission incentive adders due to the expanded incentive cap would offset the reduced annual after-tax earnings by approximately $5 million. FERC Connecticut RTO Adder Complaint: On June 11, 2026, DEEP, Connecticut Office of Consumer Counsel, PURA, and the Connecticut Attorney General (collectively, the CT Agencies) filed a complaint at FERC against CL&P and The United Illuminating Company, requesting FERC to: (1) find that CL&P’s and UI’s collection of the 50-basis points ROE adder for Regional Transmission Organization (RTO) participation is unjust and unreasonable because Connecticut law now requires RTO membership and such an incentive should not be awarded for behavior required by law; (2) direct tariff revisions to eliminate the adder in the formula rate; and (3) direct refunds of adder-related charges imposed after the refund effective date of the complaint. On June 29, 2026, CL&P and UI filed a complaint in U.S. District Court in Connecticut asserting that Connecticut Public Act 25-173 is unconstitutional in requiring ISO-NE membership. On July 1, 2026, CL&P and UI filed a motion requesting the CT RTO Adder Complaint proceeding be held in abeyance until the U.S. District Court proceeding in Connecticut is resolved. We cannot predict the outcome of the complaints at this time. Transmission Rates and Other Transmission Rates-Related Proceedings: CL&P, NSTAR Electric and PSNH transmission rates are calculated in accordance with a FERC-approved formula ratemaking framework, and each utility is required to file an annual update on or before July 31st with resulting rates effective January 1st the following year. The formula rate framework provides for an annual reconciliation of the prior calendar year actual costs incurred related to our transmission facilities, including an allowed ROE, plus forecasted information through the next rate period. The annual update process includes formula rate protocols that provide disclosure of cost inputs, an opportunity for informal discovery procedures and a challenge process, which provides transparency to stakeholders. From time to time, various matters are pending before FERC relating to transmission rates, incentives, interconnections and transmission planning. Depending on the outcome, any of these matters could materially impact our results of operations and financial condition. At this time, Eversource cannot predict the ultimate outcome of the matters currently pending before FERC, and the resulting impact on its transmission incentives or planning. Regulatory Developments and Rate Matters Electric and Natural Gas Utility Base Distribution Rates: The regulated companies’ distribution rates are set by their respective state regulatory commissions, and their tariffs include mechanisms for periodically adjusting their rates for the recovery of specific incurred costs. Other than as described below, for the first half of 2026, 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 2025 Form 10-K. Connecticut: CL&P Distribution Rate Case: On July 14, 2026, CL&P filed an application with PURA to request an increase in base distribution rates. The application proposed to amend rates to provide additional revenues of approximately $451 million annually, exclusive of the impact of catastrophic storms and pre‑staging events occurring between January 2018 and March 2025. The total revenue deficiency inclusive of the impact of these storm costs is approximately $727 million. In connection with storm cost recovery proposals, CL&P is requesting (1) the securitization of storm restoration costs incurred for catastrophic weather and pre-staging events between 2018 and 2023 (PURA is currently evaluating this proposal under separate proceedings) and (2) a prudence review of storm restoration costs incurred for catastrophic weather events between January 2024 and March 2025. Amounts deemed prudent through this review would be recovered from customers through a newly proposed storm cost recovery adjustment factor, designed to provide for annual reviews of deferred storm costs, allowing for more consistent and timely cost recovery while mitigating potential rate shock for customers. As part of the rate case, CL&P proposes to implement a performance-based multi-year rate plan that would adjust rates annually over a four-year term from July 1, 2027 through June 30, 2031, with a corresponding stay out provision. The plan includes a revenue-cap formula adjusted for inflation, a supplemental capital adjustment formula to support CL&P’s planned capital infrastructure improvements, an exogenous events 52 recovery mechanism, performance metrics and an earnings sharing mechanism, among other proposals. The proposed revenue requirement includes a regulatory return on equity of 10.25 percent with a 53.86 percent common equity ratio for CL&P’s capital structure. PURA is permitted up to 350 days in all to investigate the proposed rates and issue a final order. A decision by PURA is expected by June 29, 2027. CL&P Storm Proceeding: On March 28, 2024, PURA established a prudency review proceeding to evaluate costs reported by CL&P for catastrophic storms and pre‑staging events occurring between January 1, 2018 and December 31, 2023. Storm costs requested by CL&P for this six-year period totaled $974.2 million. CL&P additionally requested approval to recover carrying costs calculated at the weighted average cost of capital on the deferred storm costs totaling $397 million. These carrying costs reflect CL&P’s actual financing costs on the unrecovered storm costs from the date the deferred storm costs were incurred through June 1, 2027, the expected date of securitization. These carrying costs have not been deferred on the balance sheet. On July 29, 2026, PURA issued a final decision approving $869.4 million of prudently incurred catastrophic storms and pre‑staging events occurring between January 1, 2018 and December 31, 2023 and postponing review of $63.3 million of storm costs to a future proceeding. PURA did not approve the recovery of carrying costs from the date the deferred storm costs were incurred through the date of the final decision. PURA approved the accrual of carrying costs on the unrecovered, approved storm costs beginning on the date of the final decision through the date of securitization or other recovery authorized in the CL&P distribution rate case proceeding. Total approved storm costs to be considered by PURA for future securitization are $667.9 million, which excludes $101.5 million of costs that were previously collected from customers through base distribution rates and $100 million approved in the April 2026 RAM proceeding to be collected through the CTA rate from May 1, 2026 through April 30, 2027. CL&P is currently evaluating the impact of costs not allowed for recovery in the decision and potential legal courses of action. The impact of the decision will be recorded in the third quarter of 2026. On May 4, 2026, PURA issued a notice of proceeding to consider whether the issuance of rate reduction bonds for the securitization of approved storm costs is in the best interest of rate payers. A timeline in this proceeding has not yet been established. CL&P Advanced Metering Infrastructure Filing: On January 3, 2024, PURA issued a final decision regarding CL&P’s Advanced Metering Infrastructure (AMI) investment and implementation plan. In CL&P’s view, the final decision did not provide a reasonable path for cost recovery and would delay implementation. In addition, in CL&P’s view, the final decision modifies the prudence standard for recovery of costs expended on the project, improperly linking recovery to outcomes not known at the outset of the project. On January 18, 2024, CL&P submitted a motion for reconsideration to PURA, asking that the agency modify these aspects of the decision, which PURA subsequently denied on February 14, 2024. On March 6, 2024, CL&P filed written comments citing four major problems associated with PURA’s guidelines for recovery of the costs of AMI implementation, which if not addressed, represent obstacles to AMI implementation in Connecticut. On April 16, 2024, PURA issued a procedural order directing Eversource and inviting all parties and intervenors to submit pre-filed testimony pertaining to AMI. On October 17, 2024, PURA issued a proposed final decision on recovery of the costs for AMI implementation. On October 31, 2024, CL&P filed written exceptions focused on three main aspects of the proposed decision, which included (1) clarifying the prudence standard to be used in evaluating AMI investments, (2) timing of prudency reviews, and (3) cost recovery related to incremental O&M expenses. On December 4, 2024, PURA issued a final decision on the recovery of costs for AMI implementation. On December 9, 2024, CL&P filed a petition for reconsideration because PURA had not fully resolved the issues CL&P raised in its October 31, 2024 written exceptions. On November 25, 2025, PURA issued correspondence in connection with CL&P’s October 31, 2025 annual AMI compliance filing asserting that it was no longer evaluating the merits of CL&P’s petition for reconsideration, that PURA approval is not required for CL&P to deploy AMI, and that CL&P may invest in AMI at any time and seek cost recovery under the AMI tariff after meeting established filing criteria. On December 19, 2025, CL&P filed a motion responding to the legal issues raised in PURA’s correspondence and requested that PURA reopen the prior proceeding for the purpose of lawfully acting upon CL&P’s December 9, 2024 petition for reconsideration and resolving the open questions on AMI cost recovery. On July 1, 2026, PURA issued a final decision rescinding the previously approved December 2024 interim AMI cost recovery tariff framework resulting from the delay in AMI implementation, CL&P’s impending base distribution rate proceeding and the passing of legislation permitting the securitization of AMI costs. On July 14, 2026, CL&P formally submitted its AMI implementation and cost recovery proposals in conjunction with its base distribution rate case filing. In the rate case proceeding, CL&P requested approval of a new cost recovery framework to support accelerated AMI deployment, leveraging a proposed PBR capital funding mechanism and future securitization for incremental O&M and stranded legacy meter costs. On July 21, 2026, CL&P petitioned for a separate, uncontested proceeding to secure timely authorization to advance the physical deployment schedule. CL&P witnesses filed testimony, including an updated estimate of $1.3 billion for capital costs and operating expenses. CL&P requested a determination from PURA by November 2026. CL&P RAM Filing: On April 22, 2026, PURA issued an interim decision in CL&P’s Rate Adjustment Mechanisms (RAM) filing and approved rates for six RAM components, with rates effective May 1, 2026 through April 30, 2027. The rates include recovery of over- or under-collection balances as of December 31, 2025, actual costs from the prior year, and adjustments to incorporate certain known and measurable cost changes not reflected in prior year costs that CL&P will incur in 2026. As part of the RAM decision, PURA approved incremental funding of $100 million of storm restoration costs through the Competitive Transition Assessment (CTA) rate, for the period May 1, 2026 to April 30, 2027. This incremental funding provides interim recovery for a portion of CL&P’s deferred storm costs. Massachusetts: NSTAR Gas Distribution Rates: NSTAR Gas’ PBR mechanism allows for an annual adjustment to base distribution rates for inflation and exogenous events. On June 15, 2026, NSTAR Gas submitted its annual PBR Adjustment filing reflecting a $19.8 million increase to base distribution rates, of which, $19.7 million was associated with an inflation-based adjustment and the remainder for a prior period exogenous cost adjustment, for effect on November 1, 2026. DPU approval is expected by October 30, 2026. 53 New Hampshire: PSNH Distribution Rates: PSNH’s alternative regulatory framework allows three formulaic annual revenue adjustments on August 1, 2026, 2027 and 2028. On April 1, 2026, PSNH submitted its first annual alternative regulatory framework filing reflecting a calculated $23.6 million in supplemental revenue support to be included in base distribution rates, for effect August 1, 2026. On July 21, 2026, the NHPUC approved this filing. Legislative, Policy and Legal Matters New Hampshire: On April 15, 2026, New Hampshire enacted legislation authorizing electric utilities to recover certain storm‑related costs through securitization, subject to approval by the NHPUC. Under the legislation, eligible storm costs include prudently incurred costs associated with storm preparation, emergency response, and system restoration activities, as well as related financing and transaction costs. Recovery through securitization would occur pursuant to one or more NHPUC finance orders issued following a utility petition and hearing process. If approved, securitized costs would be recovered over a defined period through customer charges designed to provide timely recovery of principal, interest, and associated expenses, generally at interest rates lower than PSNH’s authorized return on equity. This legislation provides a potential alternative to traditional storm cost recovery mechanisms and is intended to mitigate the near‑term cash flow and customer bill impacts of significant storm events. While the legislation does not affect the recovery of storm costs previously incurred, it may influence the manner and timing of recovery of qualifying storm costs incurred in future periods. 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 2025 Form 10-K. There have been no material changes with regard to these critical accounting policies. Refer to Note 9C, “Commitments and Contingencies - FERC ROE Complaints” to the financial statement for further discussion of the critical estimates surrounding the FERC regulatory liability. Also refer to Note 9E, “Commitments and Contingencies - Offshore Wind Sale and Contingent Liability,” to the financial statements for further discussion of the critical accounting estimates surrounding the offshore wind contingent liability. Other Matters Website: 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. 54 RESULTS OF OPERATIONS – EVERSOURCE ENERGY AND SUBSIDIARIES The following provides the amounts and variances in operating revenues and expense line items in the statements of income for Eversource for the three and six months ended June 30, 2026 and 2025 included in this combined Quarterly Report on Form 10-Q: For the Three Months Ended June 30, For the Six Months Ended June 30, (Millions of Dollars) 2026 2025 Increase/(Decrease) 2026 2025 Increase/(Decrease) Operating Revenues $ 2,903.2 $ 2,838.1 $ 65.1 $ 7,407.6 $ 6,956.4 $ 451.2 Operating Expenses: Purchased Power, Purchased Natural Gas and Transmission 939.5 818.7 120.8 2,457.7 2,159.1 298.6 Operations and Maintenance 480.4 467.6 12.8 987.4 955.0 32.4 Depreciation 423.9 385.6 38.3 844.4 765.2 79.2 Amortization (44.3) 109.1 (153.4) 358.4 564.6 (206.2) Energy Efficiency Programs 173.2 135.3 37.9 464.8 392.8 72.0 Taxes Other Than Income Taxes 278.2 258.8 19.4 566.5 530.3 36.2 Sale of Aquarion 111.4 — 111.4 111.4 — 111.4 Total Operating Expenses 2,362.3 2,175.1 187.2 5,790.6 5,367.0 423.6 Operating Income 540.9 663.0 (122.1) 1,617.0 1,589.4 27.6 Interest Expense 355.4 293.2 62.2 720.7 594.0 126.7 Loss on Offshore Wind 194.0 — 194.0 194.0 — 194.0 Other Income, Net 144.0 95.4 48.6 245.2 187.7 57.5 Income Before Income Tax Expense 135.5 465.2 (329.7) 947.5 1,183.1 (235.6) Income Tax Expense 79.9 110.6 (30.7) 283.2 275.8 7.4 Net Income 55.6 354.6 (299.0) 664.3 907.3 (243.0) Net Income Attributable to Noncontrolling Interests 1.9 1.9 — 3.8 3.8 — Net Income Attributable to Common Shareholders $ 53.7 $ 352.7 $ (299.0) $ 660.5 $ 903.5 $ (243.0) Operating Revenues Sales Volumes: A summary of our retail electric GWh sales volumes and our firm natural gas MMcf sales volumes, and percentage changes, is as follows: Electric Firm Natural Gas Sales Volumes (GWh) Percentage Increase/(Decrease) Sales Volumes (MMcf) Percentage Increase/(Decrease) Three Months Ended June 30: 2026 2025 2026 2025 Traditional 1,834 1,816 1.0 % — — — % Decoupled 10,084 10,122 (0.4) % 26,330 26,161 0.6 % Total Sales Volumes 11,918 11,938 (0.2) % 26,330 26,161 0.6 % Six Months Ended June 30: Traditional 3,901 3,846 1.4 % — — — % Decoupled 21,343 21,064 1.3 % 93,573 94,448 (0.9) % Total Sales Volumes 25,244 24,910 1.3 % 93,573 94,448 (0.9) % Weather, fluctuations in energy supply rates, conservation measures (including utility-sponsored energy efficiency programs), and economic conditions affect customer energy usage. In our service territories, weather impacts electric 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, and Yankee Gas, 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. 55 Operating Revenues: The variance in Operating Revenues by segment is as follows: For the Three Months Ended June 30, For the Six Months Ended June 30, (Millions of Dollars) 2026 2025 Increase/ (Decrease) 2026 2025 Increase/ (Decrease) Electric Distribution $ 2,183.5 $ 2,166.4 $ 17.1 $ 5,124.0 $ 4,944.1 $ 179.9 Natural Gas Distribution 528.7 460.8 67.9 1,901.8 1,602.1 299.7 Electric Transmission 581.0 568.7 12.3 1,165.7 1,116.5 49.2 Water Distribution 62.4 61.1 1.3 116.0 111.3 4.7 Other 439.8 405.8 34.0 924.3 844.9 79.4 Eliminations (892.2) (824.7) (67.5) (1,824.2) (1,662.5) (161.7) Total Operating Revenues $ 2,903.2 $ 2,838.1 $ 65.1 $ 7,407.6 $ 6,956.4 $ 451.2 Electric and Natural Gas Distribution Revenues: Base Distribution Revenues: Base distribution rates are the approved, regulated charges to recover the utility’s cost of service, including operations and building and maintaining infrastructure, that allow utilities to recover investments and earn a reasonable return. Base distribution rates are established in base rate proceedings and approved by state regulators. Fluctuations in base distribution revenues impact earnings. Base distribution revenues include the impact of the revenue decoupling mechanism, which qualifies as an alternative revenue program (ARP). The increase at Electric Distribution for the three and six month periods is due primarily to base distribution rate increases at NSTAR Electric effective January 1, 2026 and at PSNH effective August 1, 2025. The increase at Natural Gas Distribution for the three and six month periods is due primarily to base distribution rate increases effective November 1, 2025 at Yankee Gas, NSTAR Gas and EGMA, and also a shift in recovery of certain GSEP investments from tracked revenues into base rates, which does not impact total revenues or earnings. Three Months Ended June 30, For the Six Months Ended June 30, (Millions of Dollars) 2026 2025 Increase 2026 2025 Increase Base Electric Distribution Revenues $ 704.3 $ 681.6 $ 22.7 $ 1,469.9 $ 1,423.5 $ 46.4 Base Natural Gas Distribution Revenues 232.9 176.9 56.0 841.2 603.1 238.1 NSTAR Electric’s PBR mechanism allows for an annual adjustment to base distribution rates for inflation, exogenous events and future capital additions based on a historical five-year average of total capital additions. On December 30, 2025, the DPU approved a $55.1 million increase to base distribution rates for effect on January 1, 2026. On July 25, 2025, the NHPUC approved a permanent rate increase to base distribution rates of $100.7 million, effective August 1, 2025 at PSNH. NSTAR Gas’ PBR mechanism allows for an annual adjustment to base distribution rates for inflation and exogenous events. On October 29, 2025, the DPU approved a $117.6 million increase to base distribution rates for effect on November 1, 2025. On January 16, 2026, the DPU approved a joint settlement agreement between NSTAR Gas and the Massachusetts Office of the Attorney General that allowed for a $45.0 million increase to base distribution rates effective January 1, 2026 related to non-GSEP plant additions. EGMA was allowed two rate base resets in a DPU-approved October 7, 2020 rate settlement agreement, with the first rate base reset on November 1, 2024. EGMA’s base distribution rates were increased effective November 1, 2025 to incorporate a $62.2 million remaining revenue requirement. PURA issued a final decision in the Yankee Gas distribution rate case on November 5, 2025 that was subsequently updated on March 11, 2026, that included a distribution rate increase of $86.7 million, effective November 1, 2025. The approved revenue requirement includes a previously recorded rate credit of $37.4 million plus carrying charges for non-firm margin credits over three years beginning November 1, 2025. Excluding the rate credit, the distribution rate increase totaled $100.1 million. Tracked Distribution Revenues: Tracked distribution revenues consist of certain costs that are recovered from customers in retail rates on a fully reconciling basis through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs has no impact on earnings. Costs recovered through cost tracking mechanisms include, among others, •energy supply and natural gas supply procurement; •electric retail transmission charges; •state-mandated charges incurred in furtherance of grid reliability, affordability, clean energy and other energy policy directives from the state, such as energy purchase agreements required by legislation and regulation and other energy-related costs, energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), hardship and low income programs, net metering for distributed generation, and additionally for NSTAR Electric solar-related programs; and •other delivery costs, such as certain capital tracking mechanisms for infrastructure improvements, and additionally for the Massachusetts utilities, pension and PBOP benefits. Revenues from certain of these cost tracking mechanisms also include certain incentives earned, return on capital tracking mechanisms, and carrying charges that are billed in rates to customers, which do impact earnings. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market, sales of natural gas to third-party marketers, and the sale of RECs to various counterparties. 56 Customers have the choice to purchase electricity from their Eversource electric utility or from a competitive third-party supplier. For customers who have contracted separately with these competitive suppliers, revenue is not recorded for the sale of the electricity commodity, as the utility is acting as an agent on behalf of the third-party supplier. For customers that choose to purchase electric generation from CL&P, NSTAR Electric or PSNH, each utility purchases power on behalf of, and is permitted to recover the related energy supply cost without mark-up from, its customers, and records offsetting amounts in revenues and purchased power related to this energy supply procurement. CL&P, NSTAR Electric and PSNH each remain as the distribution service provider for all customers and charge a regulated rate for distribution delivery service recorded in revenues. Certain eligible natural gas customers may elect to purchase natural gas from their Eversource natural gas utility or may contract separately with a gas supply operator. Revenue is not recorded for the sale of the natural gas commodity to customers who have contracted separately with these operators, only the delivery to a customer, as the utility is acting as an agent on behalf of the gas supply operator. The variance in tracked distribution revenues is due primarily to the following: For the Three Months Ended June 30, Electric Distribution Natural Gas Distribution (Millions of Dollars) 2026 2025 Increase/(Decrease) 2026 2025 Increase/(Decrease) Retail Tariff Tracked Revenues: Energy supply procurement $ 419.3 $ 367.3 $ 52.0 $ 195.2 $ 140.2 $ 55.0 Retail transmission 476.4 428.2 48.2 — — — State-mandated charges 186.6 372.8 (186.2) 53.3 44.9 8.4 Other delivery 149.7 135.9 13.8 19.7 47.3 (27.6) Wholesale Market Sales Revenue 219.9 155.2 64.7 24.8 48.9 (24.1) For the Six Months Ended June 30, Electric Distribution Natural Gas Distribution (Millions of Dollars) 2026 2025 Increase/ (Decrease) 2026 2025 Increase/ (Decrease) Retail Tariff Tracked Revenues: Energy supply procurement $ 995.5 $ 874.1 $ 121.4 $ 733.1 $ 547.2 $ 185.9 Retail transmission 997.8 879.0 118.8 — — — State-mandated charges 539.8 920.5 (380.7) 196.3 186.1 10.2 Other delivery 329.2 296.6 32.6 41.3 147.5 (106.2) Wholesale Market Sales Revenue 741.1 502.9 238.2 84.2 111.3 (27.1) Operating Revenues do not directly correlate to charges on a customer’s bill and cannot be used to determine the percentage of a customer’s bill that contributes to various charges or programs. Differences between total company operating revenues and rates on a customer’s bill can arise due to customer class allocations and rate design, application of regulatory accounting, and other factors. For customers who have contracted with competitive third-party suppliers or gas supply operators, revenue is not recorded for the sale of the electricity or natural gas commodity, which, for those customers, represents a significant portion of a bill but is not reflected in total company operating revenues. Fluctuations in retail tariff tracked revenues are driven by adjustments to retail rates to recover costs and changes in sales volumes. Energy supply procurement: The increase in energy supply procurement within electric distribution for the three and six month periods was driven by higher average prices and higher average supply-related sales volumes. The increase in energy supply procurement within natural gas distribution for the three month period was driven by higher average prices, partially offset by lower average supply-related sales volumes. The increase in energy supply procurement within natural gas distribution for the six month period was driven by higher average prices and higher average supply-related sales volumes. State-mandated charges: The variance in state-mandated charges for the three and six month periods was primarily driven by changes in the retail NBFMCC rate at CL&P and the retail LTRCA rate at NSTAR Electric. The CL&P NBFMCC rate includes the recovery of costs incurred under long-term state mandated energy purchase contracts with the Millstone and Seabrook nuclear power plants, net of the benefits received from selling this energy into the ISO-NE wholesale market. The NBFMCC rate changes primarily resulted from the timing of recovery of net costs associated with these power purchase agreements. The NSTAR Electric LTRCA rate includes recovery of costs incurred under the long-term state mandated energy purchase contract with Hydro-Québec that began in the first quarter of 2026, net of the benefits received from selling this energy into the ISO-NE wholesale market. 57 CL&P is required by both state legislation and regulation to purchase electric generation from Millstone and Seabrook under PURA-approved PPAs entered in 2019. NSTAR Electric is required by both state legislation and regulation to purchase renewable hydroelectric energy and renewable energy attributes from Hydro-Québec under a DPU-approved PPA entered in 2018. CL&P and NSTAR Electric do not have legislative authority to use this purchased output to serve their customer loads and therefore they sell the energy into the wholesale market and use the proceeds from the energy sales to offset the contract costs. The net cost or net sales amount is recovered from, or refunded to, customers in the non-bypassable component of the CL&P retail FMCC rate and the retail LTRCA rate at NSTAR Electric. CL&P and NSTAR Electric do not earn any margin or return from the sale of these contracted outputs, which solely offsets the cost of the legislatively required purchases from Millstone and Seabrook for CL&P and Hydro-Québec for NSTAR Electric. Changes in CL&P’s NBFMCC and NSTAR Electric’s LTRCA retail revenues and CL&P’s and NSTAR Electric’s wholesale market sales, as compared to the actual costs incurred, are deferred on the income statement by an offset to amortization expense (for CL&P) or purchased power expense (for NSTAR Electric). Other delivery: The decrease in other delivery for the three and six month periods at the natural gas distribution business is due primarily to a shift in recovery of certain GSEP investments into base rates, which does not impact total revenues or earnings. Wholesale market sales revenue: The increase in electric distribution wholesale market sales revenue for the three and six month periods was due primarily to the sale of output from the Hydro-Québec PPA at NSTAR Electric, which began in the first quarter of 2026. The increase was also due to higher average electricity market prices received for wholesale sales at CL&P. ISO-NE average market prices received for CL&P’s wholesale sales increased to an average price of $44.23 per MWh and $83.01 per MWh for the three and six months ended June 30, 2026, as compared to $39.07 per MWh and $72.46 per MWh for the same periods in 2025. The increase in the ISO-NE average market prices was driven primarily by higher 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 with CL&P and the Hydro-Québec PPA with NSTAR Electric. Electric Transmission Revenues: Electric transmission revenues increased $12.3 million and $49.2 million for the three and six month periods, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure. The increase was partially offset by the impact from the March 19, 2026 FERC decision in the FERC base ROE complaints that lowered the allowed ROE from 10.57 percent to 9.57 percent. The six month period also includes a decrease in revenues due to the impact of a regulatory liability established for revenues subject to refund that was recorded in the first quarter of 2026 as a result of the March 2026 FERC decision of $31.9 million. For further information, see "FERC Regulatory Matters - FERC ROE Complaints" in this Management's Discussion and Analysis of Financial Condition and Results of Operations. 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 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 to the following: (Millions of Dollars) Three Months Ended Six Months Ended Energy supply procurement costs $ 51.8 $ 122.7 Other electric distribution costs 27.2 16.5 Natural gas supply costs 31.8 127.6 Transmission costs 41.4 105.9 Eliminations (31.4) (74.1) Total Purchased Power, Purchased Natural Gas and Transmission $ 120.8 $ 298.6 The variance in energy supply procurement costs is offset in Operating Revenues (tracked energy supply procurement revenues). The increase in other electric distribution costs for the three month period is due primarily to an increase in the LTRCA related to NSTAR Electric’s PPA with Hydro-Québec, for which costs began in the first quarter of 2026, and an increase in transition costs at PSNH. These increases were partially offset by lower net metering costs at NSTAR Electric and lower long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism at CL&P. The increase in other electric distribution costs for the six month period is due primarily to an increase in the LTRCA related to NSTAR Electric’s PPA with Hydro-Québec, for which costs began in the first quarter of 2026. The increase was partially offset by lower net metering costs at NSTAR Electric, lower long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism at CL&P, and a decrease in transition costs at PSNH resulting from higher Regional Greenhouse Gas Initiatives (RGGI) proceeds received, which are credited back to customers. Costs at the natural gas distribution segment relate to supply procurement costs for retail customers. Total natural gas costs increased for the three month period due primarily to higher average purchased volumes and an increase in the retail cost deferral, partially offset by lower average prices. Total natural gas costs increased for the six month period due primarily to higher average prices, higher average purchased volumes, and an increase in the retail cost deferral. 58 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 system. The increase in transmission costs for the three month period is 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 in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers. These increases were partially offset by a decrease in costs billed by ISO-NE that support regional grid investments. The increase in transmission costs for the six month period is due primarily to an increase in costs billed by ISO-NE, an increase in Local Network Service charges, and an increase in the retail transmission cost deferral. 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 to the following: (Millions of Dollars) Three Months Ended Six Months Ended Base Electric Distribution (Non-Tracked Costs): Storm costs $ (10.4) $ (1.4) Employee-related expenses (including labor and benefits) (6.0) (14.0) Shared corporate costs (including IT system depreciation at Eversource Service) 3.7 9.0 General corporate costs (including vendor services in corporate areas, uncollectible expense, insurance, fees and assessments) 6.4 1.3 Operations-related expenses (including vegetation management, vendor services, vehicles and materials) 1.8 2.5 Total Base Electric Distribution (Non-Tracked Costs) (4.5) (2.6) Tracked Electric Costs (Electric Distribution and Electric Transmission) 18.6 30.9 Total Electric Distribution and Electric Transmission 14.1 28.3 Natural Gas Distribution: Base (Non-Tracked Costs) - Increase due primarily to higher uncollectible expense and shared corporate costs 2.6 22.2 Tracked Costs - Decrease due primarily to lower uncollectible expense (1.2) (8.0) Total Natural Gas Distribution 1.4 14.2 Water Distribution 2.1 2.0 Eversource Parent and Other Companies - other operations and maintenance 33.0 75.6 Eliminations (37.8) (87.7) Total Operations and Maintenance $ 12.8 $ 32.4 Depreciation expense increased for the three and six month periods due primarily to higher net plant in service balances and higher depreciation rates at Yankee Gas resulting from the November 2025 rate case decision. 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. The variance in Amortization for the three and six month periods is due primarily to the deferral adjustments of energy-related and other tracked costs at CL&P (included in the non-bypassable component of the FMCC mechanism and the SBC mechanism), NSTAR Electric and PSNH, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The CL&P non-bypassable FMCC rates and the SBC retail rates in effect for the three and six month periods of 2026 were lower than those in effect for the three and six month periods of 2025. These lower collections, as compared to the actual costs incurred, resulted in a decrease to amortization expense for the three and six month periods of $116.2 million and $127.8 million for the CL&P non-bypassable FMCC mechanism, respectively, and $49.3 million and $86.7 million for the CL&P SBC deferral adjustment, respectively. Energy Efficiency Programs expense includes costs of various state energy policy initiatives and expanded energy efficiency programs that are recovered from customers in rates, most of which have no impact on earnings. Energy Efficiency Programs expense includes a deferral adjustment that reflects the actual costs of energy efficiency programs compared to the amounts billed to customers, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. Energy Efficiency Programs expense increased for the three and six month periods due primarily to the deferral adjustment, partially offset by lower program spending. Taxes Other Than Income Taxes expense increased for the three and six month periods due primarily to higher property taxes as a result of higher utility plant balances across our subsidiaries and higher Connecticut gross earnings taxes. Sale of Aquarion relates to a charge of $111.4 million associated with the loss on the sale of the Aquarion water distribution business. See “Business Development and Capital Expenditures - Sale of Aquarion Water Distribution Business” included in this Management’s Discussion and Analysis of Financial Condition and Results of Operations for further information. 59 Interest Expense increased for the three and six month periods due to the following: (Millions of Dollars) Three Months Ended Six Months Ended Long-term debt $ 37.8 $ 69.2 Capitalized AFUDC related to debt funds 6.8 5.0 Amortization of debt discounts and premiums, net 0.1 0.7 Regulatory deferrals (due primarily to interest expense accrued on the FERC ROE regulatory liability of $1.3 million and $30.1 million recorded in the second quarter and first half of 2026, respectively) 29.9 76.8 Short-term notes payable (12.2) (24.4) RRBs (0.4) (0.8) Other 0.2 0.2 Total Interest Expense $ 62.2 $ 126.7 Loss on Offshore Wind relates to the pre-tax charge of $194 million in the second quarter of 2026 associated with increasing our offshore wind contingent liability for expected future payments associated with the Revolution Wind project. See “Earnings Overview - Offshore Wind Contingent Liability” included in this Management’s Discussion and Analysis of Financial Condition and Results of Operations for further information. Other Income, Net increased for the three and six month periods due to the following: (Millions of Dollars) Three Months Ended Six Months Ended Pension, SERP and PBOP Non-Service Income Components, Net of Deferred Portion $ 6.8 $ 18.4 Interest Income (primarily on regulatory deferrals) 1.8 (3.8) Capitalized AFUDC related to equity funds 5.3 5.3 Equity in Earnings of Unconsolidated Affiliates 0.3 (1.9) Investment (Loss)/Income (1.4) 0.9 Other (including the gain on sale of an intangible asset in the second quarter of 2026) 35.8 38.6 Total Other Income, Net $ 48.6 $ 57.5 Income Tax Expense decreased for the three month period due primarily to lower pre-tax earnings ($69.2 million), lower state taxes ($5.9 million), and an increase in amortization of EDIT ($3.6 million), partially offset by an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($48.0 million). Income Tax Expense increased for the six month period due to lower pre-tax earnings ($49.5 million), and increases due primarily to higher state taxes ($4.4 million) and an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($60.0 million), partially offset by an increase in amortization of EDIT ($6.7 million), and lower share-based payment tax deficiency ($0.8 million). 60 RESULTS OF OPERATIONS – THE CONNECTICUT LIGHT AND POWER COMPANY NSTAR ELECTRIC COMPANY AND SUBSIDIARY PUBLIC SERVICE COMPANY OF NEW HAMPSHIRE AND SUBSIDIARIES The following provides the amounts and variances in operating revenues and expense line items in the statements of income for CL&P, NSTAR Electric and PSNH for the six months ended June 30, 2026 and 2025 included in this combined Quarterly Report on Form 10-Q: For the Six Months Ended June 30, CL&P NSTAR Electric PSNH (Millions of Dollars) 2026 2025 Increase/ (Decrease) 2026 2025 Increase/ (Decrease) 2026 2025 Increase/ (Decrease) Operating Revenues $ 2,617.8 $ 2,673.4 $ (55.6) $ 2,069.0 $ 1,883.2 $ 185.8 $ 717.5 $ 651.1 $ 66.4 Operating Expenses: Purchased Power and Transmission 1,049.1 874.5 174.6 537.3 534.7 2.6 154.9 119.3 35.6 Operations and Maintenance 384.2 390.9 (6.7) 386.7 342.5 44.2 128.8 138.0 (9.2) Depreciation 224.8 214.4 10.4 239.3 217.4 21.9 89.4 81.7 7.7 Amortization of Regulatory Assets, Net 202.1 418.0 (215.9) 90.0 67.7 22.3 34.9 47.7 (12.8) Energy Efficiency Programs 68.0 91.7 (23.7) 193.3 107.7 85.6 18.3 22.7 (4.4) Taxes Other Than Income Taxes 230.1 221.0 9.1 159.6 152.0 7.6 55.8 53.0 2.8 Total Operating Expenses 2,158.3 2,210.5 (52.2) 1,606.2 1,422.0 184.2 482.1 462.4 19.7 Operating Income 459.5 462.9 (3.4) 462.8 461.2 1.6 235.4 188.7 46.7 Interest Expense 138.4 97.6 40.8 152.7 114.6 38.1 55.3 41.1 14.2 Other Income, Net 34.8 30.1 4.7 105.8 94.0 11.8 20.9 24.5 (3.6) Income Before Income Tax Expense 355.9 395.4 (39.5) 415.9 440.6 (24.7) 201.0 172.1 28.9 Income Tax Expense 86.4 100.5 (14.1) 96.2 104.5 (8.3) 49.2 41.9 7.3 Net Income $ 269.5 $ 294.9 $ (25.4) $ 319.7 $ 336.1 $ (16.4) $ 151.8 $ 130.2 $ 21.6 Operating Revenues Sales Volumes: A summary of our retail electric GWh sales volumes is as follows: For the Six Months Ended June 30, 2026 2025 Percentage Increase CL&P 10,017 9,881 1.4 % NSTAR Electric 11,326 11,183 1.3 % PSNH 3,901 3,846 1.4 % 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 $55.6 million at CL&P, increased $185.8 million at NSTAR Electric and $66.4 million at PSNH for the six month period. Base Distribution Revenues: Base distribution rates are the approved, regulated charges to recover the utility’s cost of service, including operations and building and maintaining infrastructure, that allow utilities to recover investments and earn a reasonable return. Base distribution rates are established in base rate proceedings and approved by state regulators. Fluctuations in base distribution revenues impact earnings. Base distribution revenues include the impact of the revenue decoupling mechanism, which qualifies as an ARP. The increases at NSTAR Electric and PSNH are due to base distribution rate increases effective January 1, 2026 and August 1, 2025, respectively. For the Six Months Ended June 30, CL&P NSTAR Electric PSNH (Millions of Dollars) 2026 2025 Increase 2026 2025 Increase 2026 2025 Increase Base Distribution Revenues $ 564.5 $ 564.5 $ — $ 640.0 $ 614.8 $ 25.2 $ 265.4 $ 244.2 $ 21.2 Tracked Distribution Revenues: Tracked distribution revenues consist of certain costs that are recovered from customers in retail rates on a fully reconciling basis through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs has no impact on earnings. Costs recovered through cost tracking mechanisms include, among others, •energy supply procurement; •retail transmission charges; •state-mandated charges incurred in furtherance of grid reliability, affordability, clean energy and other energy policy directives from the state, such as energy purchase agreements required by legislation and regulation and other energy-related costs, energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), hardship and low income programs, net metering for distributed generation, and additionally for NSTAR Electric solar-related programs; and 61 •other delivery costs, such as certain capital tracking mechanisms for infrastructure improvements, and additionally for NSTAR Electric, pension and PBOP benefits. Revenues from certain of these cost tracking mechanisms also include certain incentives earned, return on capital tracking mechanisms, and carrying charges that are billed in rates to customers, which do impact earnings. Tracked revenues also include wholesale market sales transactions, such as sales of energy and energy-related products into the ISO-NE wholesale electricity market and the sale of RECs to various counterparties. Customers have the choice to purchase electricity from their Eversource electric utility or from a competitive third-party supplier. For customers who have contracted separately with these competitive suppliers, revenue is not recorded for the sale of the electricity commodity, as the utility is acting as an agent on behalf of the third-party supplier. For customers that choose to purchase electric generation from CL&P, NSTAR Electric or PSNH, each utility purchases power on behalf of, and is permitted to recover the related energy supply cost without mark-up from, its customers, and records offsetting amounts in revenues and purchased power related to this energy supply procurement. CL&P, NSTAR Electric and PSNH each remain as the distribution service provider for all customers and charge a regulated rate for distribution delivery service recorded in revenues. The variance in tracked distribution revenues is due primarily to the following: For the Six Months Ended June 30, CL&P NSTAR Electric PSNH (Millions of Dollars) 2026 2025 Increase/ (Decrease) 2026 2025 Increase/ (Decrease) 2026 2025 Increase/ (Decrease) Retail Tariff Tracked Revenues: Energy supply procurement $ 665.8 $ 529.0 $ 136.8 $ 180.4 $ 232.1 $ (51.7) $ 149.3 $ 113.0 $ 36.3 Retail transmission 409.3 311.2 98.1 438.6 434.3 4.3 149.9 133.5 16.4 State-mandated charges 198.5 594.7 (396.2) 305.0 272.0 33.0 36.3 53.8 (17.5) Other delivery 143.5 138.2 5.3 184.7 156.0 28.7 1.0 2.4 (1.4) Wholesale Market Sales Revenue 500.2 394.7 105.5 222.2 89.4 132.8 18.7 18.8 (0.1) Operating Revenues do not directly correlate to charges on a customer’s bill and cannot be used to determine the percentage of a customer’s bill that contributes to various charges or programs. Differences between total company operating revenues and rates on a customer’s bill can arise due to customer class allocations and rate design, application of regulatory accounting, and other factors. For customers who have contracted with competitive third-party suppliers, revenue is not recorded for the sale of the electricity commodity, which, for those customers, represents a significant portion of a bill but is not reflected in total company operating revenues. Fluctuations in retail tariff tracked revenues are driven by adjustments to retail rates to recover costs and changes in sales volumes. Energy supply procurement: The increase in energy supply procurement at CL&P and PSNH for the six month period was driven by higher average prices and higher average supply-related sales volumes. The decrease in energy supply procurement at NSTAR Electric for the six month period was driven by lower average supply-related sales volumes, partially offset by higher average prices. State-mandated charges: The variance in state-mandated charges for the six month period was primarily driven by changes in the retail NBFMCC rate at CL&P and the retail LTRCA rate at NSTAR Electric. The CL&P NBFMCC rate includes the recovery of costs incurred under long-term state mandated energy purchase contracts with the Millstone and Seabrook nuclear power plants, net of the benefits received from selling this energy into the ISO-NE wholesale market. The NBFMCC rate changes primarily resulted from the timing of recovery of net costs associated with these power purchase agreements. The NSTAR Electric LTRCA rate includes recovery of costs incurred under the long-term state mandated energy purchase contract with Hydro-Québec that began in the first quarter of 2026, net of the benefits received from selling this energy into the ISO-NE wholesale market. CL&P is required by both state legislation and regulation to purchase electric generation from Millstone and Seabrook under PURA-approved PPAs entered in 2019. NSTAR Electric is required by both state legislation and regulation to purchase renewable hydroelectric energy and renewable energy attributes from Hydro-Québec under a DPU-approved PPA entered in 2018. CL&P and NSTAR Electric do not have legislative authority to use this purchased output to serve their customer loads and therefore they sell the energy into the wholesale market and use the proceeds from the energy sales to offset the contract costs. The net cost or net sales amount is recovered from, or refunded to, customers in the non-bypassable component of the CL&P retail FMCC rate and the retail LTRCA rate at NSTAR Electric. CL&P and NSTAR Electric do not earn any margin or return from the sale of these contracted outputs, which solely offsets the cost of the legislatively required purchases from Millstone and Seabrook for CL&P and Hydro-Québec for NSTAR Electric. Changes in CL&P’s NBFMCC and NSTAR Electric’s LTRCA retail revenues and CL&P’s and NSTAR Electric’s wholesale market sales, as compared to the actual costs incurred, are deferred on the income statement by an offset to amortization expense (for CL&P) or purchased power expense (for NSTAR Electric). Wholesale market sales revenue: The increase in CL&P’s wholesale market sales revenue for the six month period was due primarily to higher average electricity market prices received for wholesale sales. ISO-NE average market prices received for CL&P’s wholesale sales increased to an average price of $83.01 per MWh for the six months ended June 30, 2026, as compared to $72.46 per MWh for the same period in 2025. The increase in the ISO-NE average market prices was driven primarily by higher natural gas prices in New England. The increase in wholesale market revenues at NSTAR Electric is due primarily to the sale of output from the Hydro-Québec PPA, which began in the first quarter of 2026. 62 Volumes sold into the market were primarily from the sale of output generated by the Millstone PPA and Seabrook PPA with CL&P and the Hydro-Québec PPA with NSTAR Electric. Transmission Revenues: Transmission revenues increased $19.2 million at CL&P, $16.8 million at NSTAR Electric, and $13.2 million at PSNH for the six month period, due primarily to a higher transmission rate base as a result of our continued investment in our transmission infrastructure. These increases were partially offset by the impact of a regulatory liability established for revenues subject to refund that was recorded in the first quarter of 2026 as a result of the March 19, 2026 FERC decision in the FERC base ROE complaints of $15.4 million, $12.6 million, and $3.9 million for CL&P, NSTAR Electric and PSNH, respectively, and the impact from the March FERC decision that lowered the allowed ROE from 10.57 percent to 9.57 percent. For further information, see "FERC Regulatory Matters - FERC ROE Complaints" in this Management's Discussion and Analysis of Financial Condition and Results of Operations. Eliminations: Eliminations are related to the Eversource electric transmission revenues that are derived from ISO-NE regional transmission charges to the distribution businesses of CL&P, NSTAR Electric and PSNH that recover the costs of the wholesale transmission business in rates charged to their customers. The impact of eliminations decreased revenues by $23.8 million at CL&P, $6.1 million at NSTAR Electric, and $2.4 million at PSNH for the six month period. Purchased Power and Transmission expense includes costs associated with providing electric generation service supply to all customers who have not migrated to third-party suppliers, the cost of energy purchase contracts entered into as required by regulation, and transmission costs. These energy supply procurement costs, other energy-related costs, and transmission costs are recovered from customers in rates through commission-approved cost tracking mechanisms, which have no impact on earnings (tracked costs). The variance in Purchased Power and Transmission expense is due to the following: (Millions of Dollars) CL&P NSTAR Electric PSNH Energy supply procurement costs $ 137.2 $ (52.0) $ 37.5 Other electric distribution costs (26.6) 56.8 (13.7) Transmission costs 87.8 3.9 14.2 Eliminations (23.8) (6.1) (2.4) Total Purchased Power and Transmission $ 174.6 $ 2.6 $ 35.6 The variance in energy supply procurement costs is offset in Operating Revenues (tracked energy supply procurement revenues). The variance in other electric distribution costs at NSTAR Electric is due primarily to an increase in the LTRCA related to NSTAR Electric’s PPA with Hydro-Québec, for which costs began in the first quarter of 2026, partially offset by lower net metering costs, at CL&P is due to lower long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism, and at PSNH is due to a decrease in transition costs resulting from higher RGGI proceeds received, which are credited back to customers. 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 system. •The increase in transmission costs at CL&P was due primarily to an increase in costs billed by ISO-NE that support regional grid investments, an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network and an increase in the retail transmission cost deferral, which reflects the actual costs of transmission service compared to estimated amounts billed to customers. •The increase in transmission costs at NSTAR Electric was due primarily to an increase in Local Network Service charges, partially offset by a decrease in costs billed by ISO-NE and a decrease in the retail transmission cost deferral. •The increase in transmission costs at PSNH was due primarily to an increase in Local Network Service charges and an increase in the retail transmission cost deferral, partially offset by a decrease in costs billed by ISO-NE. 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 to the following: (Millions of Dollars) CL&P NSTAR Electric PSNH Base Electric Distribution (Non-Tracked Costs): Storm costs $ (3.6) $ 3.1 $ (0.9) Shared corporate costs (including IT system depreciation at Eversource Service) 2.3 5.7 1.0 Employee-related expenses (including labor and benefits) (8.7) (1.2) (4.1) Vegetation Management 4.6 4.5 (3.4) General corporate costs (including vendor services in corporate areas, uncollectible expense, insurance, fees and assessments) 11.5 (3.2) (7.0) Operations-related expenses (including vendor services, vehicles and materials) (3.7) 4.5 (4.0) Total Base Electric Distribution (Non-Tracked Costs) 2.4 13.4 (18.4) Total Tracked Costs - Increase at NSTAR Electric due primarily to higher advanced metering infrastructure costs, higher transmission expense and higher uncollectible expense (9.1) 30.8 9.2 Total Operations and Maintenance $ (6.7) $ 44.2 $ (9.2) 63 Depreciation expense increased for the six month period for CL&P, NSTAR Electric and PSNH due to higher net plant in service balances. Amortization of Regulatory Assets, Net expense includes the deferral of energy-related costs and other costs that are included in certain regulatory commission-approved cost tracking mechanisms. This deferral adjusts expense to match the corresponding revenues compared to the actual costs incurred. These costs are recovered from customers in rates and have no impact on earnings. Amortization expense also includes the amortization of certain costs as those costs are collected in rates. The variance in Amortization of Regulatory Assets, Net for the six month period is due primarily to the following: •The variance at CL&P was due primarily to the deferral adjustment of energy-related and other tracked costs that are included in the non-bypassable component of the FMCC mechanism and the SBC mechanism, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The CL&P non-bypassable FMCC rates and the SBC retail rates in effect in the six month period of 2026 were lower than those in the six month period of 2025. These lower collections, as compared to the actual costs incurred, resulted in a decrease to amortization expense of $127.8 million for the CL&P non-bypassable FMCC mechanism and $86.7 million for the CL&P SBC deferral adjustment. •The variance at NSTAR Electric was due primarily to the deferral adjustment of costs included in the solar facilities regulatory mechanism and higher recoveries of storm costs recovered in rates, partially offset by the deferral adjustment of energy-related and other tracked costs that are included in the advanced metering infrastructure regulatory mechanism. •The variance at PSNH was due primarily to the completion of certain storm amortization and amortization of overcollections in the Pole Plant Adjustment Mechanism and the energy efficiency regulatory mechanisms, both of which were phased out as part of the 2025 NHPUC-approved distribution rate case and are being fully refunded to customers. These decreases were partially offset by an increase in the stranded cost recovery mechanism. Energy Efficiency Programs expense includes costs of various state energy policy initiatives and expanded energy efficiency programs that are recovered from customers in rates, most of which have no impact on earnings. Energy Efficiency Programs expense includes a deferral adjustment that reflects the actual costs of energy efficiency programs compared to the amounts billed to customers, which can fluctuate from period to period based on the timing of costs incurred and related rate changes to recover these costs. The variance in Energy Efficiency Programs expense for the six month period is due primarily to the following: •The decrease at CL&P was due to lower program spending and the deferral adjustment. •The increase at NSTAR Electric was due to the deferral adjustment, partially offset by lower program spending. •The decrease at PSNH was due to the deferral adjustment, partially offset by higher program spending. Taxes Other Than Income Taxes - the variance is due primarily to the following: •The increases at CL&P, NSTAR Electric and PSNH were due to higher property taxes as a result of higher utility plant balances. Interest Expense - the variance is due to the following: (Millions of Dollars) CL&P NSTAR Electric PSNH Long-term debt $ (0.8) $ 14.1 $ 6.4 Capitalized AFUDC related to debt funds 1.8 0.1 0.7 Amortization of debt discounts and premiums, net (0.4) — 0.4 Regulatory deferrals (due primarily to interest expense accrued on the FERC ROE regulatory liability of $14.4 million, $12.0 million and $3.7 million, respectively, recorded in the first half of 2026) 40.4 27.8 9.1 Short-term notes payable (0.2) (3.8) (1.5) RRBs — — (0.8) Other — (0.1) (0.1) Total Interest Expense $ 40.8 $ 38.1 $ 14.2 Other Income, Net - the variance is due to the following: (Millions of Dollars) CL&P NSTAR Electric PSNH Pension, SERP and PBOP Non-Service Income Components, Net of Deferred Portion $ 5.6 $ 7.1 $ 1.6 Interest Income (primarily on regulatory deferrals) (6.3) (1.2) (1.5) Capitalized AFUDC related to equity funds 6.3 3.7 (3.4) Investment (Loss)/Income (0.8) 2.3 (0.4) Other (0.1) (0.1) 0.1 Total Other Income, Net $ 4.7 $ 11.8 $ (3.6) Income Tax Expense - the variance is due primarily to the following: •The decrease at CL&P was due primarily to lower pre-tax earnings ($8.3 million), lower state taxes ($2.0 million), an increase in amortization of EDIT ($3.9 million), and lower share-based payment tax deficiency ($0.3 million), partially offset by an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.4 million). 64 •The decrease at NSTAR Electric was due primarily to lower pre-tax earnings ($5.2 million), lower state taxes ($1.6 million), lower share-based payment tax deficiency ($0.5 million), and a decrease in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($1.0 million). •The increase at PSNH was due primarily to higher pre-tax earnings ($6.0 million) and higher state taxes ($1.7 million) and an increase in items that impact our tax rate as a result of regulatory treatment (flow-through items) and permanent differences ($0.3 million), partially offset by an increase in amortization of EDIT ($0.7 million). EARNINGS SUMMARY CL&P's earnings decreased $25.4 million for the six month period due primarily to the after-tax first quarter 2026 charge of $20.8 million resulting from the March 19, 2026 FERC decision in the FERC base ROE complaints for estimated refunds with interest for the fifteen-month first complaint period, the prospective impact from the March 19, 2026 FERC decision in the FERC base ROE complaints that lowered the allowed ROE from 10.57 percent to 9.57 percent, as well higher net interest expense on regulatory deferrals, higher depreciation expense and higher property tax expense. The earnings decrease was partially offset by a higher transmission rate base as a result of our continued investment in our transmission infrastructure, higher revenues from its capital tracking mechanism due to increased electric system improvements and lower operations and maintenance expense. NSTAR Electric's earnings decreased $16.4 million for the six month period due primarily to the after-tax first quarter 2026 charge of $17.6 million resulting from the March 19, 2026 FERC decision in the FERC base ROE complaints for estimated refunds with interest for the fifteen-month first complaint period, the prospective impact from the March 19, 2026 FERC decision in the FERC base ROE complaints that lowered the allowed ROE from 10.57 percent to 9.57 percent, as well as higher depreciation expense, higher operations and maintenance expense, lower earnings from its grid modernization tracking mechanism, higher interest expense on long-term debt and higher net interest expense on regulatory deferrals. The earnings decrease was partially offset by higher revenues as a result of the base distribution rate increase effective January 1, 2026, a higher transmission rate base as a result of our continued investment in our transmission infrastructure and higher earnings from its AMI capital tracking mechanism. PSNH's earnings increased $21.6 million for the six month period due primarily to higher revenues as a result of the base distribution rate increase effective August 1, 2025, a higher transmission rate base as a result of our continued investment in our transmission infrastructure, and lower operations and maintenance expense. The earnings increase was partially offset by the after-tax first quarter 2026 charge of $5.5 million resulting from the March 19, 2026 FERC decision in the FERC base ROE complaints for estimated refunds with interest for the fifteen-month first complaint period, the prospective impact from the March 19, 2026 FERC decision in the FERC base ROE complaints that lowered the allowed ROE from 10.57 percent to 9.57 percent, higher interest expense on long-term debt and higher net interest expense on regulatory deferrals. LIQUIDITY Cash Flows: CL&P had cash flows provided by operating activities of $497.9 million for the six months ended June 30, 2026, as compared to $753.6 million in the same period of 2025. The decrease in operating cash flows was due primarily to a $195.1 million increase in income tax payments made in 2026 as compared to 2025, a decrease in recoveries of the non-bypassable FMCC and the SBC regulatory tracking mechanism driven by the timing of collections and the timing of cash payments made on our accounts payable. These unfavorable impacts were partially offset by an improvement in regulatory recoveries for retail and wholesale transmission costs and other regulatory cost tracking mechanisms driven by the timing of cash collections, the timing of cash collections on our accounts receivable, a $5.7 million decrease in cost of removal expenditures and the timing of other working capital items. The impacts of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Assets, Net on the statements of cash flows. NSTAR Electric had cash flows provided by operating activities of $626.1 million for the six months ended June 30, 2026, as compared to $393.6 million in the same period of 2025. The increase in operating cash flows was due primarily to the timing of cash collections on our accounts receivable, an increase of $87.2 million in operating cash flows due to income tax refunds received in 2026 compared to income tax payments made in 2025, a $25.0 million decrease in cost of removal expenditures, and the timing of other working capital items. These favorable impacts were partially offset by the timing of cash payments made on our accounts payable, an increase of $42.8 million in cash payments to vendors for storm costs and an increase in regulatory recoveries driven primarily by the timing of collections for energy supply costs and other regulatory cost tracking mechanisms. The impacts of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Assets, Net on the statements of cash flows. Additionally, under a winter electric bill relief program in Massachusetts, bill credits were provided to electric customers in the first quarter of 2026, which resulted in delayed collections that will be recovered later in 2026, and were partially offset by proceeds of $84.1 million received from the Commonwealth of Massachusetts at NSTAR Electric in January 2026 to fund a portion of the bill relief. PSNH had cash flows provided by operating activities of $230.9 million for the six months ended June 30, 2026, as compared to $191.9 million in the same period of 2025. The increase in operating cash flows was due primarily to a decrease of $29.3 million in cash payments to vendors for storm costs, the timing of cash collections on our accounts receivable, and a $4.9 million decrease in cost of removal expenditures partially offset by the timing of cash payments made on our accounts payable, an increase in regulatory recoveries driven primarily by the timing of collections for energy supply costs and other regulatory cost tracking mechanisms, an increase of $7.5 million in tax payments made in 2026 compared to 2025 and the timing of other working capital items. The impacts of regulatory collections are included in both Regulatory Recoveries and Amortization of Regulatory Assets, Net on the statements of cash flows. 65 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.