STAR GROUP, L.P.

1. Organization

Star Group, L.P. (“Star,” the “Company,” “we,” “us,” or “our”) is a full service provider specializing in the sale of home heating and air conditioning products and services to residential and commercial home heating oil and propane customers. The Company hasone reportable segment for accounting purposes. We also sell diesel fuel, gasoline and home heating oil on a delivery only basis. We believe we are the nation’s largest retail distributor of home heating oil based upon sales volume.

The Company is organized as follows:

•

Star is a limited partnership, which at December 31, 2025, had outstanding 32.9 million Common Units (NYSE: “SGU”), representing a 99.0% limited partner interest in Star, and 0.3 million general partner units, representing a 1.0% general partner interest in Star. Our general partner is Kestrel Heat, LLC, a Delaware limited liability company (“Kestrel Heat” or the “general partner”). The Board of Directors of Kestrel Heat (the “Board”) is appointed by its sole member, Kestrel Energy Partners, LLC, a Delaware limited liability company (“Kestrel”). Although Star is a partnership, it is taxed as a corporation and its distributions to unitholders are treated as taxable dividends.

•

Star owns 100% of Star Acquisitions, Inc. (“SA”), a Minnesota corporation that owns 100% of Petro Holdings, Inc. (“Petro”). SA and its subsidiaries are subject to Federal and state corporate income taxes. Star’s operations are conducted through Petro and its subsidiaries. Petro is primarily a Northeast and Mid-Atlantic U.S. region retail distributor of home heating oil and propane that at December 31, 2025 served approximately 404,900 full service residential and commercial home heating oil and propane accounts and 65,200 accounts on a delivery only basis. We also sell gasoline and diesel fuel to approximately 27,600 accounts. We install, maintain, and repair heating and air conditioning equipment and to a lesser extent provide these services outside our heating oil and propane customer base including approximately 20,400 service contracts for natural gas and other heating systems.

•

Petroleum Heat and Power Co., Inc. (“PH&P”) is a wholly owned subsidiary of Star. PH&P is the borrower and Star is the guarantor of the seventh amended and restated credit agreement’s $210 million five-year senior secured term loan and the $400 million ($475 million during the heating season of December through April of each year) revolving credit facility, both due September 27, 2029. (See Note 11—Long-Term Debt and Bank Facility Borrowings).

2. Summary of Significant Accounting Policies

Basis of Presentation

The Consolidated Financial Statements include the accounts of Star and its subsidiaries. All material intercompany items and transactions have been eliminated in consolidation.

The financial information included herein is unaudited; however, such information reflects all adjustments (consisting solely of normal recurring adjustments), which are, in the opinion of management, necessary for the fair statement of financial condition and results for the interim periods. Due to the seasonal nature of the Company’s business, the results of operations and cash flows for the three-month period ended December 31, 2025 are not necessarily indicative of the results to be expected for the full year.

These interim financial statements of the Company have been prepared in accordance with U.S. Generally Accepted Accounting Principles (“GAAP”) for interim financial information and Rule 10-01 of Regulation S-X of the U.S. Securities and Exchange Commission (the “SEC”) and should be read in conjunction with the financial statements included in the Company’s Annual Report on Form 10-K for the year ended September 30, 2025.

Comprehensive Income

Comprehensive income is comprised of Net income and Other comprehensive income. Other comprehensive income consists of the unrealized gain on amortization on the Company’s pension plan obligation for its frozen defined benefit pension plan, unrealized gain on available-for-sale investments, unrealized gain (loss) on interest rate hedges and the corresponding tax effects.

Cash, Cash Equivalents, and Restricted Cash

The Company considers all highly liquid investments with an original maturity ofthree months or less when purchased to be cash equivalents. At December 31, 2025, the $20.1 million of cash, cash equivalents, and restricted cash on the Condensed Consolidated Statements of Cash Flows is composed of $19.9 million of cash and cash equivalents and $0.3 million of restricted cash. At September 30, 2025, the $24.9 million of cash, cash equivalents, and restricted cash on the Condensed Consolidated Statements of Cash Flows is composed of $24.7 million of cash and cash equivalents and $0.3 million of restricted cash. Restricted cash represents deposits held by our captive insurance company that are required by state insurance regulations to remain in the captive insurance company as cash.

Fair Value Valuation Approach

The Company uses valuation approaches that maximize the use of observable inputs and minimize the use of unobservable inputs to the extent possible. The Company determines fair value based on assumptions that market participants would use in pricing an asset or liability in the principal or most advantageous market. When considering market participant assumptions in fair value measurements, the following fair value hierarchy distinguishes between observable and unobservable inputs, which are categorized in one of the following levels:

•

Level 1 inputs: Unadjusted quoted prices in active markets for identical assets or liabilities accessible to the reporting entity at the measurement date.

•

Level 2 inputs: Other than quoted prices included in Level 1 inputs that are observable for the asset or liability, either directly or indirectly, for substantially the full term of the asset or liability.

•

Level 3 inputs: Unobservable inputs for the asset or liability used to measure fair value to the extent that observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at measurement date.

Captive Insurance Collateral

The captive insurance collateral is held by our captive insurance company in an irrevocable trust as collateral for certain workers’ compensation and automobile liability claims. The collateral is required by a third party insurance carrier that insures per claim amounts above a set deductible. If we did not deposit cash into the trust, the third party carrier would require that we issue an equal amount of letters of credit, which would reduce our availability under the credit agreement. Due to the expected timing of claim payments, the nature of the collateral agreement with the carrier, and our captive insurance company’s source of other operating cash, such as future premiums and earnings on investments, the collateral is not expected to be used to pay obligations within the next twelve months.

Unrealized gains and losses, net of related income taxes, are reported as accumulated other comprehensive income (loss), except for losses from impairments which are determined to be other-than-temporary. Realized gains and losses, and declines in value judged to be other-than-temporary on available-for-sale securities are included in the determination of net income and are included in Interest expense, net, at which time the average cost basis of these securities are adjusted to fair value.

Weather Hedge Contract

To partially mitigate the adverse effect of warm weather on cash flows, the Company has used weather hedge contracts for a number of years. Weather hedge contracts are recorded in accordance with the intrinsic value method defined by the Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 815-45-15 Derivatives and Hedging, Weather Derivatives (EITF 99-2). The premium paid is included in the caption “Prepaid expenses and other current assets” in the accompanying balance sheets and amortized over the life of the contract, with the intrinsic value method applied at each interim period.

The Company entered into weather hedge contracts for fiscal years 2026 and 2025. The hedge period runs from November 1 through March 31, taken as a whole. The “Payment Thresholds,” or strikes, are set at various levels and are referenced against degree days for the prior ten year average. For each fiscal year under these contracts, the maximum amount the Company could receive is $15.0 million and is additionally obligated to make an annual payment capped at $5.0 million if degree days exceed the Payment Threshold.

The temperatures experienced during the hedge period through December 31, 2025, were colder than the strikes in the weather hedge contracts. As a result as of December 31, 2025, we increased delivery and branch expense under those weather hedge contracts by $5.0 million. The final settlement under the weather hedge contracts for fiscal 2026 may differ depending on the actual degree-days recorded in the period from January 1, 2026 through March 31, 2026. As of December 31, 2024, in accordance with ASC 815-45, we didnot incur a benefit or expense related to the weather hedge contracts.

New England Teamsters and Trucking Industry Pension Fund (“the NETTI Fund”) Liability

As of December 31, 2025, we had $0.3 million and $15.2 million included in the captions “Accrued expenses and other current liabilities” and “Other long-term liabilities,” respectively, on our Condensed Consolidated Balance Sheet representing the remaining balance of the NETTI Fund withdrawal liability. As of September 30, 2025, we had $0.3 million and $15.3 million reflected in these categories respectively. Based on the borrowing rates currently available to the Company for long-term financing of a similar maturity, the fair value of the NETTI Fund withdrawal liability as of December 31, 2025, and September 30, 2025, was $18.2 million and $18.3 million, respectively. We utilized Level 2 inputs in the fair value hierarchy of valuation techniques to determine the fair value of this liability.

Recently Adopted Accounting Pronouncements

No new Accounting Pronouncements were adopted through the fiscal three months ended December 31, 2025.

Recently Issued Accounting Pronouncements

In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to income tax disclosures, which requires that an entity, on an annual basis, disclose additional income tax information, primarily related to the rate reconciliation and income taxes paid. The standard is effective for fiscal years beginning after December 15, 2024. Adoption is either with a prospective method or a fully retrospective method of transition. Early adoption is permitted. The Company is currently evaluating the impact of the new standard on its consolidated financial statements and related disclosures.

In November 2024, the FASB issued ASU 2024-03, Income Statement – Reporting Comprehensive Income – Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses, requiring disclosure in the notes to the financial statements for specified information about certain costs and expenses. Additionally, in January 2025, the FASB issued ASU 2025-01 to clarify the effective date of ASU 2024-03. The standard is effective for fiscal years beginning after December 15, 2026, and interim periods within annual reporting periods beginning after December 15, 2027, with early adoption and retrospective application permitted. We are currently evaluating the impact of this standard on our consolidated financial statements and related disclosures.

In July 2025, the FASB issued ASU 2025-05, Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses for Accounts Receivable and Contract Assets, which provides a practical expedient for all entities to simplify the estimation of expected credit losses on current accounts receivable and current contract assets arising from revenue contracts under Topic 606. The standard is effective for fiscal years beginning after December 15, 2025, with early adoption permitted. We are currently evaluating the impact of this standard on our consolidated financial statements and related disclosures.

In September 2025, the FASB issued ASU 2025-06, Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software, which modernizes the guidance on capitalizing costs for internal-use software by eliminating predefined development stages and introducing a principles-based approach focused on probable completion and use. The standard is effective for fiscal years beginning after December 15, 2027, with early adoption permitted. We are currently evaluating the impact of this standard on our consolidated financial statements and related disclosures.

3. Revenue Recognition

The following disaggregates our revenue by major sources for the three months ended December 31, 2025, and December 31, 2024:

Deferred Contract Costs

We recognize an asset for incremental commission expenses paid to sales personnel in conjunction with obtaining new residential customer product and equipment maintenance service contracts. We defer these costs only when we have determined the commissions are, in fact, incremental and would not have been incurred absent the customer contract. Costs to obtain a contract are amortized and recorded ratably as delivery and branch expenses over the period representing the transfer of goods or services to which the assets relate. Costs to obtain new residential product and equipment maintenance service contracts are amortized as expense over the estimated customer relationship period of approximately five years. Deferred contract costs are classified as current or non-current within “Prepaid expenses and other current assets” and “Deferred charges and other assets, net,” respectively. At December 31, 2025, the amount of deferred contract costs included in “Prepaid expenses and other current assets” and “Deferred charges and other assets, net” was $2.8 million and $4.4 million, respectively. At September 30, 2025, the amount of deferred contract costs included in “Prepaid expenses and other current assets” and “Deferred charges and other assets, net” was $2.8 million and $4.2 million, respectively. For the three months ended December 31, 2025, we recognized expense of $0.8 million and for the three months ended December 31, 2024, we recognized expense of $0.8 million associated with the amortization of deferred contract costs within “Delivery and branch expenses” in the Condensed Consolidated Statement of Operations.

Contract Liability Balances

The Company has contract liabilities for advanced payments received from customers for future oil deliveries (primarily amounts received from customers on “smart pay” budget payment plans in advance of oil deliveries) and obligations to service customers with equipment maintenance service contracts. Contract liabilities are recognized straight-line over the service contract period, generallyone year or less. As of December 31, 2025 and September 30, 2025 the Company had contract liabilities of $133.1 million and $149.7 million, respectively. During the three months ended December 31, 2025, the Company recognized $83.7 million of revenue that was included in the September 30, 2025 contract liability balance. During the three months ended December 31, 2024, the Company recognized $88.9 million of revenue that was included in the September 30, 2024 contract liability balance.

Receivables and Allowance for Doubtful Accounts

Accounts receivables from customers are recorded at the invoiced amounts. Finance charges may be applied to trade receivables that are more than 30 days past due, and are recorded as finance charge income.

The allowance for doubtful accounts is the Company’s estimate of the amount of trade receivables that may not be collectible. The allowance is determined at an aggregate level by grouping accounts based on certain account criteria and its receivable aging. The allowance is based on both quantitative and qualitative factors, including historical loss experience, historical collection patterns, overdue status, aging trends, current and future economic conditions. The Company has an established process to periodically review current and past due trade receivable balances to determine the adequacy of the allowance. No single statistic or measurement determines the adequacy of the allowance. The total allowance reflects management’s estimate of losses inherent in its trade receivables at the balance sheet date. Different assumptions or changes in economic conditions could result in material changes to the allowance for doubtful accounts.

Changes in the allowance for credit losses are as follows:

4. Common Unit Repurchase and Retirement

In July 2012, the Board adopted a plan to repurchase certain of the Company’s Common Units (the “Repurchase Plan”). Through May 2023, the Company had repurchased approximately 20.5 million Common Units under the Repurchase Plan. In May 2023, the Board authorized an increase of the number of Common Units that remained available for the Company to repurchase from 1.1 million to a total of 2.6 million, of which, approximately 2.3 million were available for repurchase in open market transactions and approximately 0.3 million were available for repurchase in privately-negotiated transactions. There is no guarantee of the number of units that will be purchased under the Repurchase Plan and the Company may discontinue purchases at any time. The Repurchase Plan does not have a time limit. The Board may also approve additional purchases of units from time to time in private transactions. The

Company’srepurchase activities take into account SEC safe harbor rules and guidance for issuer repurchases. All of the Common Units purchased under the Repurchase Plan will be retired.

Under the credit agreement dated September 27, 2024, in order to repurchase Common Units we must maintain Availability (as defined in the credit agreement) of not less than the greater of (i)15% of the Line Cap (lesser of the aggregate revolving commitment and the borrowing base)which was $38.3 million as of December 31, 2025 and (ii) $40 million on a historical pro forma and forward-looking basis, and a fixed charge coverage ratio of not less than 1.15 measured as of the date of repurchase or distribution. (See Note 11—Long-Term Debt and Bank Facility Borrowings).

The following table shows repurchases under the Repurchase Plan:

(a)

Amount includes repurchase costs.

(b)

In October 2025, the Company purchased 138,600 Common Units in a private transaction for aggregate consideration of approximately $1.6 million. The purchase was made within the Company’s unit repurchase plan.

(c)

Of the total available for repurchase, approximately 0.4 million units are available for repurchase in open market transactions and approximately 0.1 million units are available for repurchase in privately-negotiated transactions, under the Repurchase Plan.

5. Captive Insurance Collateral

The Company considers all of its captive insurance collateral to be Level 1 available-for-sale investments. Investments at December 31, 2025 consist of the following (in thousands):

Investments at September 30, 2025 consist of the following (in thousands):

Maturities of investments were as follows at December 31, 2025 (in thousands):

6. Derivatives and Hedging—Disclosures and Fair Value Measurements

The Company uses derivative instruments such as futures, options and swap agreements in order to mitigate exposure to market risk associated with the purchase of home heating oil for price-protected customers, physical inventory on hand, inventory in transit, priced purchase commitments and internal fuel usage. FASB ASC 815-10-05 Derivatives and Hedging, established accounting and reporting standards requiring that derivative instruments be recorded at fair value and included in the consolidated balance sheet as assets or liabilities, along with qualitative disclosures regarding the derivative activity. The Company has elected not to designate its commodity derivative instruments as hedging derivatives, but rather as economic hedges whose change in fair value is recognized in its statement of operations in the caption “(Increase) decrease in the fair value of derivative instruments.” Depending on the risk being economically hedged, realized gains and losses are recorded in cost of product, cost of installations and services, or delivery and branch expenses.

As of December 31, 2025, to hedge a substantial majority of the purchase price associated with heating oil gallons anticipated to be sold to our price-protected customers, the Company held the following derivative instruments that settle in future months to match anticipated sales:14.5 million gallons of swap contracts,5.3 million gallons of call options,6.4 million gallons of put options, and 49.9 million net gallons of synthetic call options. To hedge its physical inventory on hand, inventory in transit and basis risk, the Company, as of December 31, 2025, held 2.3 million gallons of swap contracts and 14.7 million gallons of short future contracts that settle in future months. To hedge our internal fuel usage and other activities for fiscal 2026, the Company held 5.8 million gallons of swap contracts that settle in future months.

As of December 31, 2024, to hedge a substantial majority of the purchase price associated with heating oil gallons anticipated to be sold to its price-protected customers, the Company held the following derivative instruments that settle in future months to match anticipated sales:17.2 million gallons of swap contracts,5.9 million gallons of call options,8.4 million gallons of put options, and 52.2 million net gallons of synthetic call options. To hedge its physical inventory on hand, inventory in transit and basis risk, the Company, as of December 31, 2024, held 1.1 million gallons of swap contracts and 18.5 million gallons of short future contracts that settle in future months. To hedge its internal fuel usage and other activities for fiscal 2025, the Company held 5.9 million gallons of swap contracts that settle in future months.

As of December 31, 2025, the Company has interest rate swap agreements in order to mitigate exposure to market risk associated with variable rate interest on $73.6 million, or 40%, of our long term debt. The Company has designated its interest rate swap agreements as cash flow hedging derivatives. To the extent these derivative instruments are effective and the accounting standard’s documentation requirements have been met, changes in fair value are recognized in other comprehensive income (loss) until the underlying hedged item is recognized in earnings. As of December 31, 2025, the fair value of the swap contracts was $(0.6) million. As of September 30, 2025, the notional value of the swap contracts was $74.5 million and the fair value of the swap contracts was $(0.6) million. We utilized Level 2 inputs in the fair value hierarchy of valuation techniques to determine the fair value of the swap contracts.

The Company’s derivative instruments are with the following counterparties: Bank of America, N.A., Bank of Montreal, Cargill, Inc., Citibank, N.A., Citizens Bank, N.A., JPMorgan Chase Bank, N.A., MSI GuaranteedWeather Trading Ltd., Munich Re Trading LLC and Wells Fargo Bank, N.A. The Company assesses counterparty credit risk and considers it to be low. We maintain master netting arrangements that allow for the non-conditional offsetting of amounts receivable and payable with counterparties to help manage our risks and record derivative positions on a net basis. The Company generally does not receive cash collateral from its counterparties and does not restrict the use of cash collateral it maintains at counterparties. At December 31, 2025, we didnot have any cash posted as collateral with counterparties. Positions with counterparties who are also parties to our credit agreement are collateralized under that facility. As of December 31, 2025, $9.8 million hedge positions or payable amounts were secured under the credit facility.

The Company’s Level 1 derivative assets and liabilities represent the fair value of commodity contracts used in its hedging activities that are identical and traded in active markets. The Company’s Level 2 derivative assets and liabilities represent the fair value of commodity and interest rate contracts used in its hedging activities that are valued using either directly or indirectly observable inputs, whose nature, risk and class are similar. No significant transfers of assets or liabilities have been made into and out of the Level 1 or Level 2 tiers. All derivative instruments were non-trading positions and were either a Level 1 or Level 2 instrument. The Company had no Level 3 derivative instruments. The fair market value of our Level 1 and Level 2 derivative assets and liabilities are calculated by our counter-parties and are independently validated by the Company. The Company’s calculations are, for Level 1 derivative assets and liabilities, based on the published New York Mercantile Exchange (“NYMEX”) market prices for the commodity contracts open at the end of the period. For Level 2 derivative assets and liabilities the calculations performed by the Company are based on a combination of the NYMEX published market prices and other inputs, including such factors as present value, volatility and duration.

The Company had no assets or liabilities that are measured at fair value on a nonrecurring basis subsequent to their initial recognition. The Company’s commodity financial assets and liabilities measured at fair value on a recurring basis are listed on the following table.

The Company’s commodity derivative assets (liabilities) offset by counterparty and subject to an enforceable master netting arrangement are listed on the following table.

(a)

Represents realized closed positions and includes the cost of options as they expire.

(b)

Represents the change in value of unrealized open positions and expired options.

7. Inventories

The Company’s product inventories are stated at the lower of cost and net realizable value computed on the weighted average cost method. All other inventories, representing parts and equipment are stated at the lower of cost and net realizable value using the FIFO method. The components of inventory were as follows (in thousands):

8. Property and Equipment

Property and equipment are stated at cost. Depreciation and amortization is computed over the estimated useful lives of the depreciable assets using the straight-line method (in thousands):

9. Business Combinations and Divestitures

The Company did not complete any acquisitions during the three months ended December 31, 2025.

During the three months ended December 31, 2024, the Company sold certain assets for cash proceeds of $0.3 million andacquireda heating oil business for approximately $0.7 million in cash. The gross purchase price was allocated $0.8 million to intangible assets, $0.4 million to goodwill, $0.3 million to fixed assets and reduced by $0.8 million of negative working capital.

10. Intangible Assets, net

Intangibles, net

The gross carrying amount and accumulated amortization of intangible assets subject to amortization are as follows (in thousands):

Amortization expense for intangible assets was $4.8 million for the three months ended December 31, 2025, compared to $4.5 million for the three months ended December 31, 2024.

11. Long-Term Debt and Bank Facility Borrowings

The Company’s debt is as follows (in thousands):

(a)

The face amount of the Company’s variable rate long-term debt approximates fair value.

(b)

Carrying amounts are net of unamortized debt issuance costs of $0.8 million as of December 31, 2025, and $0.9 million as of September 30, 2025.

On September 27, 2024, the Company refinanced itsfive-year term loan and the revolving credit facility with the execution of the seventh amended and restated revolving credit facility agreement (the “credit agreement”) with a bank syndicate comprised of ten participants, which enables the Company to borrow up to $400 million ($475 million during the heating season of December through April of each year) on a revolving credit facility for working capital purposes (subject to certain borrowing base limitations and coverage ratios), provides for a $210 million five-year senior secured term loan (“Term Loan”), allows for the issuance of up to $25 million in letters of credit, and has a maturity date of September 27, 2029.

The Company can increase the revolving credit facility size by $200 million without the consent of the bank group. However, the bank group is not obligated to fund the $200 million increase. If the bank group elects not to fund the increase, the Company can add additional lenders to the group, with the consent of the Agent, which shall not be unreasonably withheld. Obligations under the credit agreement are guaranteed by the Company and its subsidiaries and are secured by liens on substantially all of the Company’s assets including accounts receivable, inventory, general intangibles, real property, fixtures and equipment.

All amounts outstanding under the credit agreement become due and payable on the facility termination date of September 27, 2029. The Term Loan is repayable in quarterly payments of $5.3 million, plus an annual payment equal to 25% of the annual Excess Cash Flow as defined in the credit agreement (an amount not to exceed $4.0 million annually), less certain voluntary prepayments made during the year, with final payment at maturity. The Company was not required to make additional term loan repayments due to Excess Cash Flow for the fiscal year ended September 30, 2025.

The interest rate on the revolving credit facility and the term loan is based on a margin over Adjusted Term Secured Overnight Financing Rate ("SOFR") or a base rate. At December 31, 2025, the effective interest rate on the term loan (considering the impact of interest rate hedges) and revolving credit facility borrowings was approximately 6.9% and 6.6%, respectively, compared to 7.1% and 6.4%, respectively at September 30, 2025.

The commitment fee on the unused portion of the revolving credit facility is 0.30% from December through April, and 0.20% from May through November.

The credit agreement requires the Company to meet certain financial covenants, including a fixed charge coverage ratio of 1.10 if Availability (as defined in the credit agreement) is less than the greater of (a)12.5% of the Line Cap (lesser of the aggregate revolving commitment and the borrowing base) which was $31.9 million as of December 31, 2025 and (b) $35.0 million. In addition, as long as the Term Loan is outstanding, a senior secured leverage ratio cannot be more than 3.0 as calculated as of the quarters ending June or September, and no more than 5.5 as calculated as of the quarters ending December or March.

Certain restrictions are also imposed by the credit agreement, including restrictions on the Company’s ability to incur additional indebtedness, to pay distributions to unitholders, to pay certain inter-company dividends or distributions, repurchase units, make investments, grant liens, sell assets, make acquisitions and engage in certain other activities.

At December 31, 2025, $183.8 million of the Term Loan was outstanding, $71.9 million were outstanding under the revolving credit facility, $9.8 million hedge positions were secured under the credit agreement, and $5.1 million of letters of credit were issued and outstanding. At September 30, 2025, $189.0 million of the term loan was outstanding, no borrowings were outstanding under the revolving credit facility, $1.3 million hedge positions were secured under the credit agreement and $5.1 million of letters of credit were issued and outstanding.

At December 31, 2025, availability was $168.6 million, and the Company was in compliance with the financial covenants. At September 30, 2025, availability was $165.0 million, and the Company was in compliance with the financial covenants. The amount of availability is impacted by several factors, including: outstanding debt, the valuation of our customer list, and accounts receivable and inventory balances. Each year, during the third quarter, the valuation of our customer list is re-evaluated based on the Company's performance.

12. Income Taxes

On July 4, 2025, the One Big Beautiful Bill Act was signed into law in the U.S., which contains several changes to corporate taxation including changes to depreciation deductions, deductions for interest expense and reinstating 100% bonus depreciation on fixed assets acquired and placed in service after January 19, 2025.

The accompanying financial statements are reported on a fiscal year, however, the Company and its corporate subsidiaries file Federal and State income tax returns on a calendar year.

The current and deferred income tax expense for the three months ended December 31, 2025, and December 31, 2024, are as follows:

At December 31, 2025, we didnot have unrecognized income tax benefits.

Our continuing practice is to recognize interest and penalties related to income tax matters as a component of income tax expense. We file U.S. Federal income tax returns and various state and local returns. A number of years may elapse before an uncertain tax position is audited and finally resolved. For our Federal income tax returns we have four tax years subject to examination. In our major state tax jurisdictions of New York, Connecticut and Pennsylvania, we have four years that are subject to examination. In the state tax jurisdiction of New Jersey we have five tax years that are subject to examination. While it is often difficult to predict the final outcome or the timing of resolution of any particular uncertain tax position, based on our assessment of many factors, including past experience and interpretation of tax law, we believe that our provision for income taxes reflect the most probable outcome. This assessment relies on estimates and assumptions and may involve a series of complex judgments about future events.

13. Supplemental Disclosure of Cash Flow Information

14. Commitments and Contingencies

The Company’s operations are subject to the operating hazards and risks normally incidental to handling, storing and transporting and otherwise providing for use by consumers hazardous liquids such as home heating oil and propane. In the ordinary course of business, the Company is a defendant in various legal proceedings and litigation. The Company records a liability when it is probable that a loss has been incurred and the amount is reasonably estimable. We do not believe these matters, when considered individually or in the aggregate, could reasonably be expected to have a material adverse effect on the Company’s results of operations, financial position or liquidity.

The Company maintains insurance policies with insurers in amounts and with coverages and deductibles we believe are reasonable and prudent. However, the Company cannot assure that this insurance will be adequate to protect it from all material expenses related to current and potential future claims, legal proceedings and litigation, as certain types of claims may be excluded from our insurance coverage. If we incur substantial liability and the damages are not covered by insurance, or are in excess of policy limits, or if we incur liability at a time when we are not able to obtain liability insurance, then our business, results of operations and financial condition could be materially adversely affected.

15. Earnings Per Limited Partner Unit

The following table presents the net income allocation and per unit data:

*In any accounting period where the Company’s aggregate net income exceeds its aggregate distribution for such period, the Company is required to present net income per Limited Partner unit as if all of the earnings for the period were distributed, based on the terms of the Partnership agreement, regardless of whether those earnings would actually be distributed during a particular period from an economic or practical perspective. This allocation does not impact the Company’s overall net income or other financial results.

16. Segment Reporting

The Company operates as asingle operating and reportable segment, which is managed on a consolidated basis. Revenues are primarily derived from the sale of petroleum products, heating and air conditioning equipment, and related repair, maintenance, and other services. See Note 3 – Revenue Recognition for additional information.

The Company’s Chief Operating Decision Maker (“CODM”) is its Chief Executive Officer (“CEO”). The CODM makes key operating decisions and evaluates financial performance based on Adjusted EBITDA, defined as earnings from continuing operations before net interest expense, income taxes, depreciation and amortization, (increase) decrease in the fair value of derivatives, other income (loss), net, multiemployer pension plan withdrawal charge, gain or loss on debt redemption, goodwill impairment, and other non-cash and non-operating charges). The CODM reviews net income and Adjusted EBITDA on a monthly basis to monitor performance, compare actual results to budgets and forecasts, and assess overall operating effectiveness. The CODM also monitors significant expenses, including: cost of product, cost of installations and service, general and administrative expenses as well as components of delivery and branch expenses.

Because the Company has onlyone reportable segment, the amounts reported in the consolidated financial statements also represent the segment information, including total assets.

The following table sets forth our segment financial information:

17. Subsequent Events

Quarterly Distribution Declared

In January 2026, we declared a quarterly distribution of $0.1850 per unit, or $0.74 per unit on an annualized basis, on all Common Units with respect to the first quarter of fiscal 2026, paid on February 4, 2026, to holders of record on January 26, 2026. The amount of distributions in excess of the minimum quarterly distribution of $0.0675 are distributed in accordance with our Partnership Agreement, subject to the management incentive compensation plan. As a result, $6.1 million was paid to the Common Unit holders, $0.4 million to the General Partner unit holders (including $0.4 million of incentive distribution as provided in our Partnership Agreement) and $0.4 million to management pursuant to the management incentive compensation plan which provides for certain members of management to receive incentive distributions that would otherwise be payable to the General Partner.

Common Units Repurchased and Retired

In January 2026, in accordance with the Repurchase Plan, the Company repurchased and retired less than 0.1 million Common Units at an average price paid of $11.95 per unit.

Acqu isitions

Subsequent to December 31, 2025, the Company purchased the customer list and assets of a heating oil business for approximately $0.9 million before working capital adjustments.