CONNECTICUT LIGHT & POWER CO

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.

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 30 th is as follows:

(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.

E. Other Income, Net

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

(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:

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:

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:

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.

Regulatory Assets: The components of regulatory assets were as follows:

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.

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

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:

(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.

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:

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.

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.

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:

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:

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.

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:

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 afive-year $2.00 billion revolving credit facility. Effective October 11, 2025, the revolving credit facility’s termination date was extended forone 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 afive-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:

There wereno 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 areno 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.

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:

(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.

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:

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.

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:

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.

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:

(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 areno letters of credit issued under this guarantee. The guarantee will remain in effect until full performance of the guaranteed obligations.

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 allfour 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 allfour 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 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.

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 isfour years following the commercial operation of Revolution Wind.

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:

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:

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:

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 wereno antidilutive share awards excluded from the computation of diluted EPS.

The following table sets forth the components of basic and diluted earnings per share:

15. REVENUES

The following tables present operating revenues disaggregated by revenue source:

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 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 inthree 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, hasone 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:

(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:

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 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.