Nature of Operations - Unitil Corporation (Unitil or the Company) is a public utility holding company. Unitil and its electric and natural gas subsidiaries are subject to regulation as a holding company system by the Federal Energy Regulatory Commission (FERC) under the Energy Policy Act of 2005. The following companies are wholly owned subsidiaries of Unitil: Unitil Energy Systems, Inc. (Unitil Energy), Fitchburg Gas and Electric Light Company (Fitchburg), Northern Utilities, Inc. (Northern Utilities), Bangor Natural Gas Company, (Bangor), Maine Natural Gas Corporation (Maine Natural), collectively the "energy distribution" utilities; Granite State Gas Transmission, Inc. (Granite State); Unitil Power Corp. (Unitil Power); Aquarion Water Company of New Hampshire, Inc. (AWC-NH), Abenaki Water Co., Inc. (Abenaki), collectively the "water distribution" utilities; Unitil Realty Corp. (Unitil Realty); Unitil Service Corp. (Unitil Service); Unitil Water Corp. (Unitil Water); and its non-regulated business unit Unitil Resources, Inc. (Unitil Resources).

The Company’s earnings historically have been seasonal and typically higher in the first and fourth quarters when customers use natural gas for heating purposes.

Unitil’s principal business is the local distribution of electricity in the southeastern seacoast and capital city areas of New Hampshire and the greater Fitchburg area of north central Massachusetts, the local distribution of natural gas in southeastern New Hampshire, portions of southern Maine to the Lewiston-Auburn area, portions of central Maine including Augusta and the Bangor area, and in the greater Fitchburg area of north central Massachusetts, and the local distribution of water in New Hampshire. Unitil has five energy distribution utility subsidiaries: including Unitil Energy, which operates in New Hampshire; Fitchburg, which operates in Massachusetts; Northern Utilities, which operates in New Hampshire and Maine; Bangor, which operates in Maine; and Maine Natural, which operates in Maine. Unitil has two water distribution utility subsidiaries: including AWC-NH and Abenaki, which both operate in New Hampshire.

Granite State is an interstate gas transmission pipeline company, operating 85 miles of underground gas transmission pipeline primarily located in Maine and New Hampshire. Granite State provides Northern Utilities with interconnection to three major gas pipelines and access to domestic gas supplies in the south and Canadian gas supplies in the north. Granite State derives its revenues principally from transportation services provided to Northern Utilities and, to a lesser extent, third-party marketers.

A seventh energy utility subsidiary, Unitil Power, formerly functioned as the full requirements wholesale power supply provider for Unitil Energy, but ceased being the wholesale supplier of Unitil Energy with the implementation of industry restructuring and divested its long-term power supply contracts.

Unitil also has four other wholly owned subsidiaries: Unitil Service, Unitil Resources, Unitil Realty and Unitil Water. Unitil Service provides, at cost, a variety of administrative and professional services, including regulatory, financial, accounting, human resources, engineering, operations, technology, energy management and management services on a centralized basis to its affiliated Unitil companies. Unitil Resources is the Company’s wholly owned non-regulated subsidiary, which currently does not have any activity. Unitil Realty owns and manages the Company’s corporate office in Hampton, New Hampshire and leases this facility to Unitil Service under a long-term lease arrangement. Unitil Realty also owns land in Kingston, New Hampshire, on which Unitil Energy’s solar facility is located. Unitil Water currently has no activity.

Basis of Presentation - The accompanying unaudited consolidated financial statements of Unitil have been prepared in accordance with the instructions to Form 10-Q and include the information and footnotes required by generally accepted accounting principles. In the opinion of management, all adjustments considered necessary for a fair presentation have been included. The results of operations for the three and six months ended June 30, 2026 are not necessarily indicative of results to be expected for the year ending December 31, 2026. For additional information, refer to Note 1 of Part II to the Consolidated Financial Statements – “Summary of Significant Accounting Policies” of the Company’s Form 10-K for the year ended December 31, 2025, as filed with the Securities and Exchange Commission (SEC) on February 9, 2026, for a description of the Company’s Basis of Presentation.

Utility Revenue Recognition - Electric, Gas and Water Operating Revenues consist of billed and unbilled revenue and revenue from rate adjustment mechanisms. Billed and unbilled revenue includes delivery revenue and pass-through revenue, recognized according to tariffs approved by federal and state regulatory commissions, which determine the amount of revenue the Company will record for these items. Revenue from rate adjustment mechanisms is accrued revenue, recognized in connection with rate adjustment mechanisms, and authorized by regulators for recognition in the current period for future cash recoveries from, or credits to, customers.

Revenue is recorded when service is rendered to customers. However, the determination of sales to individual customers is based on the reading of their meters, which occurs on a systematic basis throughout the month. At the end of each calendar month, amounts delivered to customers since the date of the last meter reading are estimated and the corresponding unbilled revenues are calculated. These unbilled revenues are estimated each month based on estimated customer usage by class and applicable customer rates, taking into account current and historical weather data, assumptions pertaining to metering patterns, billing cycle statistics, and other estimates and assumptions, and are then reversed in the following month when billed to customers.

A majority of the Company’s revenue from contracts with customers continues to be recognized on a monthly basis based on applicable tariffs and customer monthly consumption. Such revenue is recognized using the invoice practical expedient, which allows an entity to recognize revenue in the amount that directly corresponds to the value transferred to the customer.

The Company’s billed and unbilled revenue meets the definition of “revenues from contracts with customers” as defined in Accounting Standards Codification (ASC) 606. Revenue recognized in connection with rate adjustment mechanisms is consistent with the definition of alternative revenue programs in ASC 980-605-25-3, as the Company has the ability to adjust rates in the future as a result of past activities or completed events. The rate adjustment mechanisms meet the criteria within ASC 980-605-25-4. In cases where allowable costs are greater than operating revenues billed in the current period for the individual rate adjustment mechanism, additional operating revenue is recognized. In cases where allowable costs are less than operating revenues billed in the current period for the individual rate adjustment mechanism, operating revenue is reduced. ASC 606 requires the Company to disclose separately the amount of revenues from contracts with customers and alternative revenue program revenues.

The Company’s electric and gas sales in Massachusetts and New Hampshire are largely decoupled. Revenue decoupling is the term given to the elimination of the dependency of a utility’s distribution revenue on the volume of electricity or gas sales. The difference between distribution revenue amounts billed to customers and the targeted revenue decoupling amounts is recognized as an increase or a decrease in Accrued Revenue, which forms the basis for resetting rates for future cash recoveries from, or credits to, customers. These revenue decoupling targets may be adjusted as a result of rate cases and other authorized adjustments that the Company files with the Massachusetts Department of Public Utilities (MDPU) and the New Hampshire Public Utilities Commission (NHPUC).

There were no water distribution revenues recognized for the three and six months ended June 30, 2026 and 2025 as the acquisitions of the AWC-NH and Abenaki closed on June 30, 2026. Please see Note 1 (Summary of Significant Accounting Policies: Acquisition of the Aquarion Water Companies) for additional details.

Income Taxes - The Company is subject to Federal and State income taxes and various other business taxes. The Company’s process for determining income tax amounts involves estimating the Company’s current tax liabilities and assessing temporary and permanent differences resulting from the timing of the deductions of expenses and recognition of taxable income for tax and book accounting purposes. These temporary differences result in deferred tax assets and liabilities, which are included in the Company’s Consolidated Balance Sheets. The Company accounts for income tax assets, liabilities and expenses in accordance with the Financial Accounting Standards Board (FASB) Codification guidance on Income Taxes. The Company classifies penalties and interest expense related to income tax liabilities as income tax expense and interest expense, respectively, in the Consolidated Statements of Earnings.

Allowance for Doubtful Accounts - The Company recognizes a provision for doubtful accounts that reflects the Company’s estimate of expected credit losses for electric, gas and water utility service accounts receivable. The allowance for doubtful accounts is calculated by applying a historical loss rate to customer account balances, and reflects management’s assessment of current and expected economic conditions, customer trends, or other factors such as the extent and duration of any shutoff or collection moratoriums. The Company also calculates the amount of written-off receivables that are recoverable through regulatory rate reconciling mechanisms. The Company’s energy distribution utilities which are under traditional cost of service regulation are authorized by regulators to recover the costs of the energy commodity portion of bad debts through rate mechanisms. Also, the electric and gas divisions of Fitchburg are authorized to recover through rates past due amounts associated with protected hardship accounts. Evaluating the adequacy of the allowance for doubtful accounts requires judgment about the assumptions used in the analysis. The

Company’s experience has been that the assumptions used in evaluating the adequacy of the allowance for doubtful accounts have proven to be reasonably accurate.

Accrued Revenue - Accrued Revenue includes the current portion of Regulatory Assets and unbilled revenues. The following table shows the components of Accrued Revenue as of June 30, 2026, June 30, 2025 and December 31, 2025.

Exchange Gas Receivable - Northern Utilities, Bangor and Fitchburg have gas exchange and storage agreements whereby gas purchases during the months of April through October are delivered to a third party. The third party delivers gas back to the Company during the months of November through March. The exchange and storage gas volumes are recorded at weighted average cost. The following table shows the components of Exchange Gas Receivable as of June 30, 2026, June 30, 2025 and December 31, 2025.

Gas Inventory - The Company uses the weighted average cost methodology to value gas inventory. The following table shows the components of Gas Inventory as of June 30, 2026, June 30, 2025 and December 31, 2025.

Utility Plant - The cost of additions to Utility Plant and the cost of renewals and betterments are capitalized. Cost of additions consists of labor, materials, services and certain indirect construction costs, including an allowance for funds used during construction (AFUDC). The costs of current repairs and minor replacements are charged to appropriate operating expense accounts. The original cost of utility plant retired or otherwise disposed of is charged to the accumulated provision for depreciation. The Company includes in its mass asset depreciation rates, which are periodically reviewed as part of its ratemaking proceedings, cost of removal amounts to provide for future negative salvage value. At June 30, 2026, June 30, 2025 and December 31, 2025, the cost of removal amounts, which are recorded on the Consolidated Balance Sheets in Cost of Removal Obligations, were estimated to be $160.6 million, $147.4 million, and $153.0 million, respectively.

Leases - The Company records assets and liabilities on the balance sheet for all leases with terms longer than 12 months. Leases are classified as either finance or operating, with classification affecting the pattern of expense recognition in the income statement. The Company has elected the practical expedient to not separate non-lease components from lease components and instead to account for

Regulatory Accounting - The Company’s principal business is the distribution of electricity, natural gas and water. Unitil Energy and Fitchburg are subject to regulation by the FERC. Fitchburg is also regulated by the MDPU, Unitil Energy is regulated by the NHPUC, Northern Utilities is regulated by the Maine Public Utility Commission (MPUC) and NHPUC, Bangor is regulated by the MPUC and Maine Natural is regulated by the MPUC. Granite State, the Company’s natural gas transmission pipeline, is regulated by the FERC. Unitil's water distribution utilities are subject to regulation by the NHPUC with regard to their rates, issuance of securities and other accounting and operational matters. Accordingly, the Company uses the Regulated Operations guidance as set forth in the FASB Codification. The Company has recorded Regulatory Assets and Regulatory Liabilities which will be recovered from customers, or applied for customer benefit, in accordance with rate provisions approved by the applicable public utility regulatory commission. The electric and gas divisions of Fitchburg are authorized to recover through rates past due amounts associated with hardship accounts that are protected from shut-off. As of June 30, 2026, June 30, 2025 and December 31, 2025, the Company has recorded $9.5 million, $8.3 million and $8.9 million, respectively, of hardship accounts in Regulatory Assets. These amounts are included in “Other Deferred Charges” in the following table. The Company currently receives recovery in rates or expects to receive recovery of these hardship accounts in future rate cases.

Generally, the Company receives a return on investment on its regulatory assets for which a cash outflow has been made. Included in Regulatory Assets as of June 30, 2026 are $8.3 million of environmental costs, rate case costs and other expenditures to be recovered over varying periods in the next seven years. Regulators have authorized recovery of these expenditures, but without a return. Regulatory commissions can reach different conclusions about the recovery of costs, which can have a material effect on the Company’s Consolidated Financial Statements. The Company believes it is probable that its regulated distribution and transmission utilities will recover their investments in long-lived assets, including regulatory assets. If the Company, or a portion of its assets or operations, were to cease meeting the criteria for application of these accounting rules, accounting standards for businesses in general would become applicable and immediate recognition of any previously deferred costs, or a portion of deferred costs, would be required in the year in which the criteria are no longer met, if such deferred costs were not recoverable in the portion of the business that continues to meet the criteria for application of the FASB Codification topic on Regulated Operations. If unable to continue to apply the FASB Codification provisions for Regulated Operations, the Company would be required to apply the provisions for the Discontinuation of Rate-Regulated Accounting included in the FASB Codification. In the Company’s opinion, its regulated operations will be subject to the FASB Codification provisions for Regulated Operations for the foreseeable future.

Derivatives - The Company’s regulated energy subsidiaries enter into energy supply contracts to serve their electric and gas customers. The Company follows a procedure for determining whether each contract qualifies as a derivative instrument under the

guidance provided by the FASB Codification on Derivatives and Hedging. For each contract, the Company reviews and documents the key terms of the contract. Based on those terms and any additional relevant components of the contract, the Company determines and documents whether the contract qualifies as a derivative instrument as defined in the FASB Codification. The Company has determined that its energy supply contracts either do not qualify as a derivative instrument under the guidance set forth in the FASB Codification, have been elected as normal purchase, or have contingencies that have not yet been met in order to establish a notional amount.

The Company has contracts that meet the definition of derivatives (see Note 6 Derivatives). Derivatives are recognized on the balance sheet at fair value as either assets or liabilities. The Company considers the amount of the derivative expected to be settled within the next twelve months as current and the remainder as long-term. Derivative instruments are presented on a gross basis in the consolidated balance sheets. Cash flows related to derivative settlements are classified as operating activities in the consolidated statements of cash flows. Regulatory assets or liabilities are recorded to offset the fair value of derivatives, as contract settlement amounts are tracked and reconciled as a pass-through to customers. Costs associated with the Purchase Power Agreement (PPA) are approved by the MDPU to be passed through to customers through the Company’s Long-Term Renewable Contract Adjustment Clause tariff and accounted for per FASB Accounting Standard Codification 980, Regulated Operations. Unrealized gains or losses resulting from the change in fair value are not recognized in the income statement. Instead, they are deferred and recorded as a regulatory asset for losses or a regulatory liability for gains.

The Company recognizes an environmental attribute asset at the allocated contract cost upon receipt of the associated certificates in the applicable registry and derecognizes the asset upon retirement, at which time the related cost is recognized in Cost of Electric Sales, which are tracked and reconciled costs as pass-through to customers. Please see Note 6 (Derivatives) for additional information.

Investments in Marketable Securities - The Company maintains a trust through which it invests in a money market fund and fixed income fund. This fund is intended to satisfy obligations under the Company’s Supplemental Executive Retirement Plan (SERP) (See additional discussion of the SERP in Note 10).

At June 30, 2026, June 30, 2025 and December 31, 2025, the fair value of the Company’s investments in these trading securities, which are recorded on the Consolidated Balance Sheets in Other Assets, was $6.4 million, $6.1 million and $6.7 million, respectively, as shown in the following table. These investments are valued based on quoted prices from active markets and are categorized in Level 1 as they are actively traded and no valuation adjustments have been applied. Changes in the fair value of these investments are recorded in Other Expense, Net.

The Company also sponsors the Unitil Corporation Deferred Compensation Plan (the “DC Plan”). The DC Plan is a non-qualified deferred compensation plan that provides a vehicle for participants to accumulate tax-deferred savings to supplement retirement income. The DC Plan, which was effective January 1, 2019, is open to senior management or other highly compensated employees as determined by the Company’s Board of Directors, and may also be used for recruitment and retention purposes for newly hired senior executives. The DC Plan design mirrors the Company’s Tax Deferred Savings and Investment Plan formula, but provides for contributions on compensation above the IRS limit, which will allow participants to defer up to 85% of base salary, and up to 85% of any cash incentive for retirement. The Company may also elect to make discretionary contributions on behalf of any participant in an amount determined by the Company’s Board of Directors. A trust has been established to invest the funds associated with the DC Plan.

At June 30, 2026, June 30, 2025 and December 31, 2025, the fair value of the Company’s investments in these trading securities related to the DC Plan, which are recorded on the Consolidated Balance Sheets in Other Assets, were $4.5 million, $2.9 million and $3.5 million, respectively, as shown in the following table. These investments are valued based on quoted prices from active markets and are categorized in Level 1 as they are actively traded and no valuation adjustments have been applied. Changes in the fair value of these investments are recorded in Other Expense, Net.

Goodwill - As of June 30, 2026, the Company had recorded goodwill of $1.6 million for Bangor and $4.0 million for Maine Natural as a result of their acquisitions in 2025. On June 30 2026, the Company completed the acquisition of AWC-NH and Abenaki resulting in the recognition of $1.2 million of goodwill. Goodwill is tested for impairment at least annually, or more frequently if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. The Company performs the annual impairment assessment of goodwill on November 1 for the gas and water reporting units. The Company generally uses a qualitative analysis assessment to determine if it was more likely than not that the fair value of the reporting unit exceeded its carrying value, including goodwill. The qualitative assessment did not identify any triggering events that would indicate potential impairment of the reporting unit. Therefore, it was determined that the fair value of the reporting unit exceeded its carrying value and no goodwill impairments were recognized during the six months ended June 30, 2026.

Energy Supply Obligations - The following discussion and table summarize the nature and amounts of the items recorded as Energy Supply Obligations (current portion) and Other Noncurrent Liabilities (noncurrent portion) on the Company’s Consolidated Balance Sheets.

Exchange Gas Obligation - Northern Utilities and Bangor enter into gas exchange agreements under which Northern Utilities and Bangor release certain gas pipeline and storage assets, resell the gas storage inventory to an asset manager and subsequently repurchase the inventory over the course of the natural gas heating season at the same price at which they sold the gas inventory to the asset manager. The gas inventory related to these agreements is recorded in Exchange Gas Receivable on the Company’s Consolidated Balance Sheets while the corresponding obligations are recorded in Energy Supply Obligations.

Renewable Energy Portfolio Standards - Renewable Energy Portfolio Standards (RPS) require retail electricity suppliers, including public utilities, to demonstrate that required percentages of their sales are met with power generated from certain types of resources or technologies. Compliance is demonstrated by purchasing and retiring Renewable Energy Certificates (REC) generated by facilities approved by the state as qualifying for REC treatment. Unitil Energy and Fitchburg purchase RECs in compliance with RPS legislation in New Hampshire and Massachusetts for supply provided to default service customers. RPS compliance costs are a supply cost that is recovered in customer default service rates. Unitil Energy and Fitchburg collect RPS compliance costs from customers throughout the year and demonstrate compliance for each calendar year on the following July 1. Due to timing differences between collection of revenue from customers and payment of REC costs to suppliers, Unitil Energy and Fitchburg typically defer costs for RPS compliance which are recorded within Accrued Revenue with a corresponding liability in Energy Supply Obligations on the Company’s Consolidated Balance Sheets.



Fitchburg has entered into long-term renewable contracts for the purchase of its pro rata share of clean energy and/or RECs under statewide procurement processes pursuant to Massachusetts legislation. The generating facilities associated with some of these contracts have been constructed and are now operating. Please see Note 7 (Regulatory Matters: Fitchburg - Massachusetts Request for Proposals) for additional details.

Recently Issued Pronouncements - In November 2024, the FASB issued ASU 2024-03, Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures, and in January 2025, the FASB issued ASU 2025-01, Income Statement - Reporting Comprehensive Income - Expense Disaggregation Disclosures: Clarifying the Effective Date. ASU 2024-03 requires public entities to disclose, in the notes to financial statements, certain costs and expenses, such as purchases of inventory, employee compensation, and costs related to depreciation and amortization. ASU 2024-03, as clarified by ASU 2025-01, is effective for the Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2027, and subsequent interim periods, with

early adoption permitted. The Company is currently evaluating the impact of these standards on its Consolidated Financial Statement disclosures.

Acquisition of Bangor Natural Gas Company - On January 31, 2025, the Company acquired all issued and outstanding shares of Bangor Natural Gas Company for $71.4 million. Through this acquisition, the Company expanded its service territory to include approximately 8,500 customers in the greater Bangor area of central Maine.

In connection with this acquisition, the Company recorded $66.7 million of net utility plant, $3.8 million working capital, $1.6 million goodwill, $0.2 million noncurrent assets and $0.9 million noncurrent regulatory liabilities.

Goodwill represents the amount by which the purchase price exceeds the estimated fair value of the net assets acquired. The goodwill related to Bangor is partially tax-deductible. The tax-deductible portion of goodwill is $0.4 million and will be amortized over 15 years.

Acquisition of Maine Natural Gas Corporation - On October 31, 2025, the Company acquired all issued and outstanding shares of Maine Natural for $91.1 million. Through this acquisition, the Company expanded its service territory to include approximately 6,300 customers in the Portland area of central Maine, as well as the capital city of Augusta.

The Company applied the acquisition method of accounting in accordance with ASC 805, Business Combinations (“ASC 805”) and recognized assets acquired and liabilities assumed at their fair value as of the date of acquisition, with the excess purchase consideration recorded to goodwill. As the Company finalizes the estimation of the fair value of the assets acquired and liabilities assumed, additional adjustments may be recorded during the measurement period (a period not to exceed 12 months from the acquisition date).

During the six months ended June 30, 2026, the Company recorded a $1.3 million net increase in goodwill resulting primarily from adjustments to regulatory liabilities during the measurement period.

In connection with this acquisition, the Company recorded $81.9 million of net utility plant, $8.4 million working capital, $4.0 million goodwill, $1.4 million noncurrent assets and $4.6 million noncurrent regulatory liabilities.

Goodwill represents the amount by which the purchase price exceeds the estimated fair value of the net assets acquired. The goodwill related to Maine Natural is partially tax-deductible. The tax-deductible portion of goodwill is $1.9 million and will be amortized over 15 years.

In connection with Unitil’s acquisition of Maine Natural, the Company entered into a Transition Service Agreement (TSA) dated October 31, 2025 between Maine Natural and Avangrid Service Company (Avangrid). Pursuant to the TSA, Avangrid will provide Maine Natural with certain services at cost, for up to 12 months, in order to continue the operations and maintenance of Maine Natural substantially consistent with past practices until Unitil has completed the successful transition. The Company has recorded $0.6 million of TSA costs for the six months ended June 30, 2026.

Acquisition of the Aquarion Water Companies - On May 6, 2025, Unitil entered into a definitive agreement to acquire Aquarion Water Company of Massachusetts, Inc., Aquarion Water Company of New Hampshire, Inc., and Abenaki Water Co., Inc. (the Aquarion Companies) from 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 subject to certain closing adjustments. The aggregate enterprise value of the sale is approximately $100.0 million, which includes approximately $70.0 million in cash and the assumption of approximately $30.0 million of debt. The transaction has been approved, subject to certain conditions, by the MDPU, the NHPUC and the MPUC.

On June 30, 2026, Unitil entered into an Amendment No. 4 to Purchase and Sale Agreement (Amendment No. 4) by and between the Company, AWA and South Central Connecticut Regional Water Authority. Amendment No. 4, among other things, further amended the Purchase Agreement by limiting the entities that the Company would purchase from AWA under the Purchase Agreement to AWC-NH and Abenaki. Except as specifically modified and amended by Amendment No. 4, the Purchase Agreement remained unchanged.

On June 30, 2026, the Company acquired all issued and outstanding shares of AWC-NH and Abenaki for $42.6 million. Through this acquisition, the Company expanded into a complementary regulated utility service to provide water service to approximately 10,700 customers in eight communities in New Hampshire.

The Company applied the acquisition method of accounting in accordance with ASC 805, Business Combinations (“ASC 805”) and recognized assets acquired and liabilities assumed at their fair value as of the date of acquisition, with the excess purchase consideration recorded to goodwill. As the Company finalizes the estimation of the fair value of the assets acquired and liabilities assumed, additional adjustments may be recorded during the measurement period (a period not to exceed 12 months from the acquisition date).

In connection with this acquisition, the Company recorded $62.0 million of net utility plant, $0.4 million working capital, $1.2 million goodwill, $1.8 million noncurrent assets, $13.5 million long-term debt, and $9.3 million noncurrent liabilities. Goodwill represents the amount by which the purchase price exceeds the estimated fair value of the net assets acquired.

In connection with Unitil’s acquisition of AWC-NH and Abenaki, the Company entered into an Operating and Transition Services Agreement (OTSA) dated June 30, 2026 between AWC-NH and Abenaki, and AWA. Pursuant to the OTSA, AWA and certain of its affiliates will provide AWC-NH and Abenaki with certain services, for up to 60 months, in order to continue the operation and maintenance of AWC-NH and Abenaki substantially consistent with past practices until AWA and Unitil have accomplished the transition of functions that were performed by AWA (or its affiliates) prior to the closing of Unitil’s acquisition of AWC-NH and Abenaki. Unitil will pay AWA a monthly payment to reimburse AWA (or its affiliates) for the actual cost of services plus a margin of 5%, subject to limitation.