STAR GROUP, L.P. - Quarter Report: 2009 December (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

(Mark One)

For the quarterly period ended December 31, 2009

OR

For the transition period from              to             

Commission File Number: 001-14129

Commission File Number: 333-103873

STAR GAS PARTNERS, L.P.

STAR GAS FINANCE COMPANY

(Exact name of registrants as specified in its charters)

(203) 328-7310

(Registrants’ telephone number, including area code)

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.    Yes  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).*    Yes  ¨    No  ¨

Indicate by check mark whether the registrants are large accelerated filers, accelerated filers, non-accelerated filers or smaller reporting companies. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Act).    Yes  ¨    No  x

At January 31, 2010, the registrants had units and shares of each issuer’s classes of common stock outstanding as follows:

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STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

INDEX TO FORM 10-Q

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STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

See accompanying notes to condensed consolidated financial statements.

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STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

See accompanying notes to condensed consolidated financial statements.

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STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL

AND COMPREHENSIVE INCOME

See accompanying notes to condensed consolidated financial statements.

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STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

See accompanying notes to condensed consolidated financial statements.

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STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

1) Partnership Organization

Star Gas Partners, L.P. (“Star Gas Partners,” the “Partnership,” “we,” “us,” or “our”) is a home heating oil distributor and services provider with one reportable operating segment that principally provides services to residential and commercial customers to heat their homes and buildings. Star Gas Partners is a master limited partnership, which at December 31, 2009, had outstanding 70.9 million common units (NYSE: “SGU”) representing 99.5% limited partner interest in Star Gas Partners, and 0.3 million general partner units, representing 0.5 % general partner interest in Star Gas Partners.

The Partnership is organized as follows:

2) Common Unit Repurchase and Retirement

On July 21, 2009, the Board of Directors of the Partnership’s General Partner authorized the repurchase of up to 7.5 million of the Partnership’s common units. The authorized common unit repurchases may be made from time-to-time in the open market, in privately negotiated transactions or in such other manner deemed appropriate by management. The program does not have a time limit. The Partnership’s repurchase activities take into account SEC safe harbor rules and guidance for issuer repurchases. All of the common units purchased in the repurchase program will be retired.

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(in thousands, except per unit amounts)

3) Summary of Significant Accounting Policies

Basis of Presentation

The Consolidated Financial Statements include the accounts of Star Gas Partners, L.P. and its subsidiaries. All material inter-company 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 Partnership’s business, the results of operations for the three-month periods ended December 31, 2009 and December 31, 2008 are not necessarily indicative of the results to be expected for the full year.

These interim financial statements of the Partnership have been prepared in accordance with accounting principles generally accepted in the United States for interim financial information and Rule 10-01 of Regulation S-X of the U.S. Securities and Exchange Commission and should be read in conjunction with the Partnership’s Annual Report on Form 10-K for the year ended September 30, 2009.

Reclassification

Certain prior year amounts have been reclassified to conform with the current year presentation.

Use of Estimates

The preparation of financial statements in accordance with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates.

Revenue Recognition

Sales of heating oil and other fuels are recognized at the time of delivery of the product to the customer and sales of heating and air conditioning equipment are recognized at the time of installation. Revenue from repairs and maintenance service is recognized upon completion of the service. Payments received from customers for heating oil equipment service contracts are deferred and amortized into income over the terms of the respective service contracts, on a straight-line basis, which generally do not exceed one year. To the extent that the Partnership anticipates that future costs for fulfilling its contractual obligations under its service maintenance contracts will exceed the amount of deferred revenue currently attributable to these contracts, the Partnership recognizes a loss in current period earnings equal to the amount that anticipated future costs exceed related deferred revenues.

Cost of Product

Cost of product includes the cost of heating oil, diesel, kerosene, heavy oil, gasoline, throughput costs, barging costs, option costs, and realized gains/losses on closed derivative positions for product sales.

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Cost of Installations and Service

Cost of installations and service includes equipment and material costs, wages and benefits for equipment technicians, dispatchers and other support personnel, subcontractor expenses, commissions and vehicle related costs.

Delivery and Branch Expenses

Delivery and branch expenses include wages and benefits and department related costs for drivers, dispatchers, mechanics, customer service, sales and marketing, compliance, credit and branch accounting, information technology and operational support.

General and Administrative Expenses

General and administrative expenses include wages and benefits and department related costs for human resources, finance and accounting, administrative support and insurance.

Allowance for Doubtful Accounts

The Partnership periodically reviews past due customer accounts receivable balances. After giving consideration to economic conditions, overdue status and other factors, it establishes an allowance for doubtful accounts, representing the Partnership’s best estimate of amounts that may not be collectible.

Allocation of Net Income (Loss)

Net income (loss) for partners’ capital and statement of operations is allocated to the general partner and the limited partners in accordance with their respective ownership percentages, after giving effect to cash distributions paid to the general partner in excess of its ownership interest, if any.

Net Income (Loss) per Limited Partner Unit

Income per limited partner unit is computed in accordance with FASB ASC 260-10-45-60 Basic and Diluted Earnings per Share topic, Participating Securities and the Two-Class Method subtopic (EITF 03-06), by dividing the limited partners’ interest in net income by the weighted average number of limited partner units outstanding. The pro forma nature of the allocation required by this standard provides that in any accounting period where the Partnership’s aggregate net income exceeds its aggregate distribution for such period, the Partnership is required to present net income per limited partner unit as if all of the earnings for the periods were distributed, 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 Partnership’s overall net income or other financial results. However, for periods in which the Partnership’s aggregate net income exceeds its aggregate distributions for such period, it will have the impact of reducing the earnings per limited partner unit, as the calculation according to this standard results in a theoretical increased allocation of undistributed earnings to the general partner. In accounting periods where aggregate net income does not exceed aggregate distributions for such period, this standard does not have any impact on the Partnership’s net income per limited partner unit calculation. A separate and independent calculation for each quarter and year-to-date period is required.

Until the quarter ended March 31, 2009, the partners had no rights to accrue or receive distributions.

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The following presents the net income allocation and per unit data using this method for the periods presented:

Cash Equivalents

The Partnership considers all highly liquid investments with a maturity of three months or less, when purchased, to be cash equivalents.

Inventories

The Partnership’s inventory of heating oil and other fuels are stated at the lower of cost computed on the weighted average cost (WAC) method, or market. All other inventories, representing parts and equipment are stated at the lower of cost computed on the FIFO method, or market.

Derivatives and Hedging – Disclosures and Fair Value Measurements

The Partnership 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 and priced purchase commitments.

To hedge a substantial majority of the purchase price associated with heating oil gallons anticipated to be sold to its price-protected customers as of December 31, 2009, the Partnership had 2.3 million gallons of swap contracts to buy heating oil; 0.1 million gallons of futures contracts to sell heating oil; 87.9 million gallons of call options; 0.7 million gallons of put options and 17.2 million net gallons of synthetic calls (a swap combined with two offsetting puts at different prices). At December 31, 2008, the Partnership had 27.3 million gallons of swap contracts to buy heating oil; 0.3 million gallons of futures contracts to sell heating oil; 86.4 million gallons of call options; 18.3 million gallons of put options and 17.0 million net gallons of synthetic calls.

To hedge the inter-month differentials for our price protected customers, its physical inventory on hand, and inventory in transit, the Partnership as of December 31, 2009 had 10.6 million gallons of future contracts to buy heating oil; 11.3 million gallons of future contracts to sell heating oil; and 30.2 million gallons of swap contracts to sell heating oil. The Partnership at December 31, 2008 had 26.7 million gallons of futures contract to buy heating oil; 34.8 million gallons of future contracts to sell heating oil; and 30.7 million gallons of swap contracts to sell heating oil.

To hedge a portion of its internal fuel usage, the Partnership as of December 31, 2009, had 1.1 million gallons of swap contracts to buy gasoline and 0.9 million gallons of swap contracts to buy diesel. The Partnership at December 31, 2008, had 1.0 million gallons of swap contracts to buy gasoline and 0.9 million gallons of swap contracts to buy diesel.

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The Partnership’s derivative instruments are with the following counterparties: Newedge USA, LLC, JPMorgan Chase Bank, NA, Societe Generale, Key Bank National Association, Cargill, Inc., Wachovia Bank, NA, and Bank of America, N.A. The Partnership maintains master netting arrangements with its counterparties to help manage counterparty credit risks and records its derivative positions on a net basis. At December 31, 2009, the aggregate cash posted as collateral in the normal course of business at counterparties was $0.3 million.

FASB ASC 815-10-05 Derivatives and Hedging topic (SFAS 133), 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. To the extent derivative instruments designated as cash flow hedges are effective and the standard’s documentation requirements have been met, changes in fair value are recognized in other comprehensive income until the underlying hedged item is recognized in earnings. The Partnership has elected not to designate its derivative instruments as hedging instruments under this standard and the change in fair value of the derivative instruments is recognized in our statement of operations in the line item (increase) decrease in the fair value of derivative instruments. Realized gains and losses are recorded in cost of product.

FASB ASC 820-10 Fair Value Measurements and Disclosures topic (SFAS 157), established a three-tier fair value hierarchy, which classified the inputs used in measuring fair value. These tiers include: Level 1, defined as observable inputs such as quoted prices for identical instruments in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions.

The Partnership’s financial assets and liabilities measured at fair value on a recurring basis are listed on the following table. The Partnership had no assets or liabilities that are measured at fair value on a nonrecurring basis subsequent to their initial recognition. All derivative instruments were non-trading positions. The market prices used to value the Partnership’s derivatives have been determined using the New York Mercantile Exchange (“NYMEX”) and independent third party prices.

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(In thousands)

(In thousands)

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Weather Hedge Contract

Weather hedge contract is recorded in accordance with the intrinsic value method defined by FASB ASC 815-45-15 Derivatives and Hedging topic, Weather Derivatives subtopic (EITF 99-2). The premium paid is amortized over the life of the contract and the intrinsic value method is applied at each interim period.

Property, Plant, and Equipment

Property, plant, and equipment are stated at cost. Depreciation is computed over the estimated useful lives of the depreciable assets using the straight-line method.

Goodwill and Intangible Assets

Goodwill and intangible assets include goodwill, customer lists and covenants not to compete.

Goodwill is the excess of cost over the fair value of net assets in the acquisition of a company. Under FASB ASC 350-10-05 Intangibles-Goodwill and Other topic (SFAS No. 142), a potential goodwill impairment is deemed to exist if the net book value of a reporting unit exceeds its estimated fair value. If goodwill of a reporting unit is determined to be impaired, the amount of impairment is measured based on the excess of the net book value of the goodwill over the implied fair value of the goodwill.

The Partnership has selected August 31 of each year to perform its annual impairment review under this standard. The evaluations utilize an Income Approach and Market Approach (consisting of the Market Comparable and the Market Transaction Approach), which contain reasonable and supportable assumptions and projections reflecting management’s best estimate in deriving the Partnership’s total enterprise value. The Income Approach calculates over a discrete period the free cash flow generated by the Partnership to determine the enterprise value. The Market Comparable approach compares the Partnership to comparable companies in similar industries to determine the enterprise value. The Market Transaction approach uses exchange prices in actual sales and purchases of comparable businesses to determine the enterprise value.

The total enterprise value as indicated by these two approaches is compared to the Partnership’s book value of net assets and reviewed in light of the Partnership’s market capitalization.

Customer lists are the names and addresses of an acquired company’s customers. Based on historical retention experience, these lists are amortized on a straight-line basis over eight to ten years.

Trade names are the names of acquired companies. Based on the economic benefit expected and historical retention experience of customers, trade names are amortized on a straight-line basis over eight to ten years.

Covenants not to compete are agreements with the owners of acquired companies and are amortized over the respective lives of the covenants on a straight-line basis, which are generally five years.

Partners’ Capital

Comprehensive income includes net income (loss), plus certain other items that are recorded directly to partners’ capital. Accumulated other comprehensive income reported on the Partnerships’ consolidated balance sheets consists of unrealized losses on pension plan obligations and the tax affect. For the three months ended December 31, 2009, comprehensive income was $12.4 million, comprised of net income of $12.0 million, an unrealized gain on pension plan obligation of $0.6 million and the tax affect of $0.2 million. For the three months ended December 31, 2008, comprehensive loss was $7.7 million, comprised of net loss of $8.0 million and an unrealized gain on pension plan obligation of $0.3 million.

Income Taxes

The Partnership is a master limited partnership and is not subject to tax at the entity level for federal and state income tax purposes. Rather, income and losses of the Partnership are allocated directly to the individual partners. While the Partnership will generate non-qualifying Master Limited Partnership revenue, distributions from the corporate subsidiaries to the Partnership are generally included in the determination of qualified Master Limited Partnership income. All or a portion of the distributions received by the Partnership from the corporate subsidiaries could be a dividend or capital gain to the partners.

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

As most of the Partnership’s income is derived from its corporate subsidiaries, these financial statements reflect significant federal and state income taxes. For corporate subsidiaries of the Partnership, a consolidated Federal income tax return is filed. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amount of assets and liabilities and their respective tax bases and operating loss carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. A valuation allowance is recognized if, based on the weight of available evidence including historical tax losses, it is more likely than not that some or all of deferred tax assets will not be realized.

Until September 30, 2009, the Partnership’s deferred tax assets and liabilities related to its corporate subsidiaries were fully offset by a valuation allowance. Approximately $86.4 million of this valuation allowance was released as of September 30, 2009 resulting in net deferred tax assets being recorded on the balance sheet. As a result of this change, any comparison of the income tax expense (benefit) in the first three fiscal quarters of 2009 to the corresponding quarters of fiscal 2010 will be comparing current income tax expense (benefit) in the fiscal 2009 quarters to both current and deferred income tax expense (benefit) in fiscal 2010 quarters. For the three months ended December 31, 2008 the Partnership recorded an income tax benefit of $0.4 million on a loss before income taxes of $8.4 million. The entire benefit recorded was for current taxes only. For the three months ended December 31, 2009 the Partnership recorded an income tax expense of $10.1 million on income before taxes of $22.1 million. The $10.1 million consists of $0.8 million in current tax expense and $9.3 million in deferred tax expense.

As of the calendar tax year ended December 31, 2009, Star Acquisitions, a wholly-owned subsidiary of the Partnership, had a federal net operating loss carry forward (“NOL”) of approximately $51 million. The NOLs, which will expire between 2018 and 2024, are generally available to offset any future taxable income. In the event that the Partnership experiences an “ownership change” for federal income tax purposes under Internal Revenue Code Section 382 (“Section 382”), Star Acquisitions may be restricted annually in its ability to use its NOLs to reduce its federal taxable income. In general, the Partnership would be deemed to have an “ownership change” under Section 382 if, immediately after any owner shift involving a 5% unitholder or any equity structure shift, the percentage of units of the Partnership owned by one or more 5% unitholder has increased by more than 50% over the lowest percentage of units of the Partnership (or any predecessor entity) owned by such unitholder at any time during the three-year testing period.

FASB ASC 740-10-05-6 Income Taxes topic, Tax Position subtopic (SFAS No. 109 and FIN 48), provides financial statement accounting guidance for uncertainty in income taxes and tax positions taken or expected to be taken in a tax return.

At December 31, 2009, we had unrecognized income tax benefits totaling $1.9 million including related accrued interest and penalties of $0.1 million. These unrecognized tax benefits are primarily the result of federal tax uncertainties. If recognized, these tax benefits and related interest and penalties would be recorded as a benefit to the effective tax rate.

We believe that the total liability for unrecognized tax benefits will decrease by $0.1 million during the next 12 months ending December 31, 2010. 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, Pennsylvania, Connecticut, and New Jersey, we have four, four, five, and five tax years, respectively, 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.

Sales, Use and Value Added Taxes

Taxes are assessed by various governmental authorities on many different types of transactions. Sales reported for product, installation and service exclude taxes.

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Recent Accounting Pronouncements

In the first quarter of fiscal 2010, the Partnership adopted the provisions of FASB ASC 805-10 Business Combinations (SFAS No. 141R). This standard establishes in a business combination principles and requirements for how an acquirer recognizes and measures identifiable assets acquired, goodwill acquired, liabilities assumed, and any noncontrolling interests.

4) Goodwill and Intangibles, net

Goodwill

A summary of changes in the Partnership’s goodwill is as follows (in thousands):

The Partnership performed its annual goodwill impairment valuation for the period ending August 31, 2009 and determined that there was no goodwill impairment.

The preparation of this analysis (see Note 3. Summary of Significant Accounting Policies – Goodwill and Intangible Assets) was based upon management’s estimates and assumptions, and future impairment calculations would be affected by actual results that are materially different from projected amounts. To provide for a sensitivity of the discount rates and transaction multiples used, ranges of high and low values are employed in the analysis, with the low values examined to ensure that a reasonably likely change in an assumption would not cause the Partnership to reach a different conclusion.

Intangibles, net

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

Amortization expense for intangible assets and deferred charges was $2.1 million for the three months ended December 31, 2009 compared to $4.4 million for the three months ended December 31, 2008. Amortization expense was lower as acquisitions from 1999 with a 10 year life became fully amortized in fiscal 2009. Total estimated annual amortization expense related to intangible assets subject to amortization and deferred charges, for the fiscal year ending September 30, 2010 and the four succeeding fiscal years ending September 30, is as follows (in thousands):

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5) Acquisitions

The Partnership made no acquisitions for the three months ended December 31, 2009.

For the three months ended December 31, 2008 the Partnership acquired one retail heating oil dealer. The aggregate purchase price was approximately $3.9 million, reduced by working capital credits of $0.7 million.

6) Long-Term Debt and Bank Facility Borrowings

The Partnership’s long-term debt is as follows (in thousands):

In January 2010, the Partnership entered into a first amendment to the amended and restated asset based revolving credit facility agreement that updated the consolidated fixed charges defined term.

At December 31, 2009 and September 30, 2009, no amount was outstanding under the revolving credit facility and $40.8 million and $40.9 million of letters of credit were issued, respectively.

Obligations under the revolving credit facility are secured by liens on substantially all assets and are guaranteed by the Partnership. The revolving credit facility imposes certain restrictions on the Partnership, including restrictions on its ability to incur additional indebtedness, to pay distributions to its unitholders, to pay inter-company dividends or distributions, make investments, grant liens, sell assets, make acquisitions and engage in certain other activities. The revolving credit facility also requires the Partnership to maintain certain financial ratios, and contains borrowing conditions and customary events of default, including nonpayment of principal or interest, violation of covenants, inaccuracy of representations and warranties, cross-defaults to other indebtedness, bankruptcy and other insolvency

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events. The occurrence of an event of default or an acceleration under the revolving credit facility would result in the Partnership’s inability to obtain further borrowings under that facility, which could adversely affect its results of operations. Such a default may also restrict the ability of the Partnership to obtain funds from its subsidiaries in order to pay interest or paydown debt. An acceleration under the revolving credit facility would result in a default under the Partnership’s other funded debt.

Under the terms of the revolving credit facility, the Partnership must maintain at all times either availability (borrowing base less amounts borrowed and letters of credit issued) of $43.5 million or a fixed charge coverage ratio (as defined in the credit agreement) of not less than 1.10x. In addition, the Partnership must maintain a fixed charge coverage ratio of 1.15x in order to make its minimum quarterly distributions of $0.0675 per unit, and 1.25x to make any distributions in excess of the minimum quarterly distributions. No inter-company dividends or distributions can be made (including those needed to pay interest or principle on the 10.25% Senior Notes) if the relevant covenant described above has not been met.

As of December 31, 2009, availability was $196 million, and the Partnership was in compliance with the fixed charge coverage ratio. As of September 30, 2009, availability was $194.4 million, and the Partnership was in compliance with the fixed charge coverage ratio.

7) Employee Pension Plan

8) Supplemental Disclosure of Cash Flow Information

9) Commitments and Contingencies

The Partnership’s operations are subject to all operating hazards and risks normally incidental to handling, storing and transporting and otherwise providing for use by consumers of combustible liquids such as home heating oil and propane. As a result, at any given time the Partnership is a defendant in various legal proceedings and litigation arising in the ordinary course of business. The Partnership maintains insurance policies with insurers in amounts and with coverages and deductibles we believe are reasonable and prudent. However, the Partnership cannot assure that this insurance will be adequate to protect it from all material expenses related to potential future claims for personal and property damage or that these levels of insurance will be available in the future at economical prices. In the opinion of management, except as described above the Partnership is not a party to any litigation, which individually or in the aggregate could reasonably be expected to have a material adverse effect on the Partnership’s results of operations, financial position or liquidity.

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10) Subsequent Events

Subsequent events have been evaluated up to February 3, 2010, the date the financial statements were issued.

Quarterly Distribution Declared

On January 21, 2010, the Partnership declared a quarterly distribution of $0.0725 per common unit (an increase of $0.005 per common unit), payable on February 12 to holders of record on February 4, 2010.

Announcement to Redeem $50 Million in Senior Notes

On January 15, 2010, the Partnership announced that it has elected to redeem $50 million in principal amount of its outstanding 10.25% Senior Notes due 2013. On February 19, 2010, the Redemption Date, the Partnership will redeem this amount at a price equal to 101.708% of face value plus any accrued but unpaid interest thereon, as provided for in the indenture. After the redemption, the outstanding face value of the 10.25% Senior Notes will be $82.5 million.

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Item 2.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Statement Regarding Forward-Looking Disclosure

This Quarterly Report on Form 10-Q includes “forward-looking statements” which represent our expectations or beliefs concerning future events that involve risks and uncertainties, including those associated with the effect of weather conditions on our financial performance, the price and supply of home heating oil, the consumption patterns of our customers, our ability to obtain satisfactory gross profit margins, our ability to obtain new accounts and retain existing accounts, our ability to make strategic acquisitions, the impact of litigation, our ability to contract for our current and future supply needs, natural gas conversions, future union relations and the outcome of current and future union negotiations, the impact of future environmental, health, and safety regulations, the ability to attract and retain employees, customer credit worthiness, counter party credit worthiness, marketing plans and general economic conditions. All statements other than statements of historical facts included in this Report including, without limitation, the statements under “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and elsewhere herein, are forward-looking statements. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we can give no assurance that such expectations will prove to be correct and actual results may differ materially from those projected as a result of certain risks and uncertainties. Important factors that could cause actual results to differ materially from our expectations (“Cautionary Statements”) include, but are not limited to, those set forth under the heading “Risk Factors” and “Business Initiatives and Strategy” in the Partnership’s Annual Report on Form 10-K (the “Form 10-K”) for the fiscal year ended September 30, 2009 and under the heading “Risk Factors” in this Quarterly Report on Form 10-Q. Without limiting the foregoing, the words “believe,” “anticipate,” “plan,” “expect,” “seek,” “estimate” and similar expressions are intended to identify forward-looking statements. All subsequent written and oral forward-looking statements attributable to the Partnership or persons acting on its behalf are expressly qualified in their entirety by the Cautionary Statements. Unless otherwise required by law, we undertake no obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise after the date of this Report.

Overview

The following is a discussion of the historical condition and results of operations of the Partnership and its subsidiaries, and should be read in conjunction with the description of our business in Item 1. “Business” of the Form 10-K and the historical Financial and Operating Data and Notes thereto included elsewhere in this Report.

Seasonality

The following matters should be considered in analyzing our financial results. Our fiscal year ends on September 30. All references to quarters and years respectively in this document are to fiscal quarters and years unless otherwise noted. The seasonal nature of our business results in the sale of approximately 30% of our volume of home heating oil in the first fiscal quarter and 45% of our volume in the second fiscal quarter of each fiscal year, the peak heating season. In addition, sales volume typically fluctuates from year to year in response to variations in weather, wholesale energy prices and other factors.

Degree Day

A “degree day” is an industry measurement of temperature designed to evaluate energy demand and consumption. Degree days are based on how far the average temperature departs from 65°F. Each degree of temperature above 65°F is counted as one cooling degree day, and each degree of temperature below 65°F is counted as one heating degree day. Degree days are accumulated each day over the course of a year and can be compared to a monthly or a long-term (multi-year) average, or normal, to see if a month or a year was warmer or cooler than usual. Degree days are officially observed by the National Weather Service and officially archived by the National Climatic Data Center. For purposes of evaluating our results of operations, we use the normal heating degree day amount as reported by the National Weather Service in our operating areas.

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EBITDA and Adjusted EBITDA (Non-GAAP Financial Measures)

EBITDA (Earnings from continuing operations before net interest expense, income taxes, depreciation and amortization) and Adjusted EBITDA are non-GAAP financial measures that are used as supplemental financial measures by management and external users of our financial statements, such as investors, commercial banks and research analysts, to assess:

Adjusted EBITDA is calculated as earnings from continuing operations before net interest expense, income taxes, depreciation and amortization, the (increase) decrease in the fair value of derivatives, gain or loss on debt redemption, goodwill impairment, and other non-cash and non-operating charges. Management believes the presentation of this measure is relevant and useful because it allows investors to view the Partnership’s performance in a manner similar to the method management uses, and makes it easier to compare its results with other companies that have different financing and capital structures. In addition, this measure is consistent with the manner in which the Partnership’s debt covenants in its material debt agreements are calculated. Both the Partnership’s 10.25% Senior Note agreement and its bank credit facility contain covenants that restrict equity distributions, acquisitions, and the amount of debt it can incur. Under the most restrictive of these covenants, which is found in the bank credit facility, the agent bank could step in and control all cash transactions for the Partnership if we failed to comply with the minimum “Availability” or the fixed charge coverage ratio. The Partnership is required to maintain either availability (borrowing base less amounts borrowed and letters of credit issued) of $43.5 million (15% of the maximum facility size) or a fixed charge coverage ratio of 1.1x (Adjusted EBITDA being a significant component of this calculation). This method of calculating Adjusted EBITDA may not be consistent with that of other companies and should be viewed in conjunction with measurements that are computed in accordance with GAAP.

Each of EBITDA and Adjusted EBITDA has its limitations as an analytical tool, and it should not be considered in isolation or as a substitute for analysis of our results as reported under GAAP. Some of the limitations of EBITDA and Adjusted EBITDA are:

Per Gallon Gross Profit Margins

We believe the change in home heating oil margins should be evaluated on a cents per gallon basis, before the effects of increases or decreases in the fair value of derivative instruments, as we believe that realized per gallon margins should not include the impact of non-cash changes in the market value of hedges before the settlement of the underlying transaction.

A significant portion of our home heating oil volume is sold to individual customers under an arrangement pre-establishing the ceiling sales price or a fixed price of home heating oil over a fixed period. When these price-protected customers agree to purchase home heating oil from us for the next heating season, we will purchase option contracts, swaps and futures contracts for a substantial majority of the heating oil that we expect to sell to these customers. The amount of home heating oil volume that we hedge per price-protected customer is based upon the estimated fuel consumption per average customer, per month. In the event that the actual usage exceeds the amount of the hedged volume on a monthly basis, we could be required to obtain additional volume at unfavorable margins. In addition, should actual usage in any month be less than the hedged volume, our hedging losses could be greater.

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Derivatives

FASB ASC 815-10-05 Derivatives and Hedging topic (FAS 133), 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. To the extent derivative instruments designated as cash flow hedges are effective, as defined under this standard, changes in fair value are recognized in other comprehensive income until the forecasted hedged item is recognized in earnings. The Partnership has elected not to designate its derivative instruments as hedging instruments under this standard, and, as a result, the changes in fair value of the derivative instruments are recognized in our statement of operations. Therefore, we experience great volatility in earnings as outstanding home heating oil derivative instruments are marked to market and non-cash gains and losses are recorded prior to the sale of the commodity to the customer. To the extent that the Partnership continues this accounting treatment, the volatility in any given period related to unrealized non-cash gains or losses on derivative home heating oil instruments can be significant to the overall results of the Partnership. However, we ultimately expect those gains and losses to be offset by the cost of product when purchased.

Weather Hedge Contract—Warm Weather

Weather conditions have a significant impact on the demand for home heating oil because our customers depend on this product principally for heating purposes. Actual weather conditions can vary substantially from year to year, significantly affecting our financial performance. To partially mitigate the adverse effect of warm weather on our cash flows, we have purchased a warm weather hedge from Swiss Re Financial Products. Under this hedge agreement, we will receive a payment of $35,000 per heating degree-day, when the total number of heating degree-days in the period covered is less than 92.5% of the 10-year average. This contract covers the period from November 1, 2009 through March 31, 2010 taken as a whole and has a maximum payout of $12.5 million.

Income Taxes—Valuation Allowance and Net Operating Loss Carry Forward

Based upon a review of a number of factors, including historical operating performance and our expectation that we could generate sustainable consolidated taxable income for the foreseeable future, we concluded at the end of fiscal 2009 that the majority of the Partnership’s net deferred tax assets should be recognized. Thus, pursuant to FASB ASC 740-10 Income Taxes topic (FAS 109), we recorded a tax benefit during fiscal 2009 reversing a majority of the opening valuation allowance, resulting in a non-cash increase in net income of $86.4 million. This benefit was partially offset by a current income tax expense of $3.8 million and deferred income tax expense of $25.0 million related to current year activity (including net operating loss carry forward utilization), resulting in a net income tax benefit of $57.6 million.

Most of the $86.4 million benefit relating to the valuation allowance release related to federal and state loss carry forwards (NOLs), insurance reserves, and the net operating book versus tax timing of intangible amortization.

The release of the valuation allowance in 2009 will also affect the comparison of income tax expense (benefit) of fiscal 2009 quarters in fiscal 2010. The income tax expense in the first three quarters of fiscal 2009 consisted of current taxes only, as any deferred income tax expense or benefit for those periods were fully offset by the valuation allowance.

At December 31, 2004, we had federal NOLs of $170.6 million and at December 31, 2009, these NOLs were reduced to approximately $51 million. Over the five year period, we utilized approximately $24 million of federal NOLs on average each year to offset our taxable income. We expect that over the next few years, we will utilize the majority of the remaining NOLs. After we exhaust the NOLs, the amount of cash taxes that we will pay will increase significantly and will reduce the annual amount of cash available for distribution to unitholders. For example, in calendar 2006, 2007, 2008 and 2009 we paid federal cash taxes of $0.1 million, $1.0 million, $0.6 million and $0.6 million, respectively. If we did not have the NOLs available to us for calendar 2006, 2007, 2008 and 2009 our federal cash taxes would have increased to $2.6 million, $17.2 million, $11.1 million and $10.1 million for calendar 2006, 2007 and 2008 and 2009, respectively.

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Income Taxes- Book Versus Tax Deductions

The amount of cash flow that we generate in any given year will depend upon a variety of factors including the amount of cash income taxes that our corporate subsidiary will pay. The amount of depreciation and amortization that we deduct for book (i.e. financial reporting) purposes will differ from the amount that our corporate subsidiary can deduct for tax purposes. The table below compares the estimated depreciation and amortization for book purposes to the amount that our corporate subsidiary expects to deduct for tax purposes. (Our corporate subsidiary files it’s tax return based on a calendar year. The amounts below are based on our fiscal year.)

(Amounts in 000’s)

Income Taxes—Consideration of Election to be Taxed as an Association or “C Corporation”

Currently, the Partnership’s main asset and source of income is an investment in Star Acquisitions, Inc. Our unitholders do not receive any of the tax benefits normally associated with owning units in a publicly traded partnership, as any cash coming from Star Acquisitions to the Partnership will generally have been taxed first at a corporate level and then may also be taxable to our unitholders as dividends, reported via annual Forms K-1. The production of the Forms K-1 themselves is an expensive and administratively intensive process. Thus, the Partnership has all the administrative issues and costs associated with being a large, publicly traded partnership, but our unitholders do not currently receive any material tax benefits from this structure.

To reduce these administrative expenses and to better rationalize our tax reporting structure, the Partnership is evaluating whether to make an election sometime in calendar 2010 or thereafter, to be treated as a corporation for federal and state income tax purposes. While the Partnership would still remain a publicly traded partnership for legal and governance purposes, for income tax purposes its unitholders would be treated as owning stock in a corporation rather than being partners in a partnership. Subsequent to the year of election unitholders would receive Forms 1099-DIV annually for any dividends and would no longer receive K-1’s. In the year of election unitholders would receive both, each form covering part of the year.

This election may have immediate short term tax implications as unitholders who own units during the calendar year of the election could receive taxable dividend income related to the deemed exchange of partnership units for stock and the "assumption" by the "new" corporation of the liabilities of the Partnership (primarily the Senior Notes).

Assuming that the Partnership’s taxable earnings and profits are equal to or less than the amount of distributions/dividends paid out during the year by the Partnership and that the unitholder holds the units for the entire calendar year, (or at least long enough during the year to receive a distribution(s) at least equal to the tax resulting from a share of dividend income reported on Form K-1), then most partners should not have any material negative cash flow consequences as a result of the Partnership making this election. Note that nothing herein should be interpreted as a projection of any future earnings amount or a projection or guarantee of future distributions or dividends.

In addition, there are risks that the Partnership could make this election but:

The Partnership intends to only make this election if it believes that it will have no overall material adverse impact on its unitholders, of which there can be no assurance. Since determining this is a function of projecting taxable earnings, making assumptions regarding the payment of distributions, and trying to determine when, during any particular calendar

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year, making the election will have the least impact on the most number of unitholders, when or, even if, it will make this election is not determinable at this time. Unitholders are encouraged to consult their tax advisors with respect to these possible outcomes.

Customer Attrition

We measure net customer attrition for our full service residential and commercial home heating oil customers. Net customer attrition is the difference between gross customer losses and customers added through internal marketing efforts. Customers purchased in acquisitions are not included in the calculation of gross customer gains, but are factored on a pro-rata basis in the denominator when calculating the percentages of gross customer gains and losses. Gains and losses at acquisitions since the acquired date of the acquisition are included in the calculation of net customer attrition. Gross customer losses are the result of a number of factors, including price competition, move-outs, credit losses and conversions to natural gas. When a customer moves out of an existing home we count the “move out” as a loss and if we are successful in signing up the new homeowner, the “move in” is treated as a gain.

Gross customer gains and gross customer losses

Net customer attrition as a percentage of the home heating oil customer base

We lost 2,600 accounts (net) during the three months ended December 31, 2009, or 0.7% of our home heating oil customer base, as compared to the three months ended December 31, 2008 in which we lost 5,500 accounts (net), or 1.4% of our home heating oil customers as the decline in gross customer gains of 7,300 accounts was less than the decline in gross customer losses of 10,200 accounts. Gross customer gains in the three months ended December 31, 2009 decreased 7,300 accounts as compared to the three months ended December 31, 2008. We believe that most of this decrease is due to the Partnership being able to take advantage of an unusually high number of consumers seeking an alternate supplier in the three months ended December 31, 2008 as a result of extreme price volatility in the summer and fall of 2008. These favorable conditions did not reoccur in the three months ended December 31, 2009, The decrease in gross customer losses of 10,200 accounts was primarily due to the aforementioned market condition, as losses due to price declined by 5,000 accounts. In addition, our credit losses improved by 3,100 accounts and natural gas conversions declined by 1,200 accounts.

We believe that the continued adverse economic conditions and price volatility will adversely impact our ability to attract customers and retain existing customers in the future.

Results of Operations

The following is a discussion of the results of operations of the Partnership and its subsidiaries, and should be read in conjunction with the historical Financial and Operating Data and Notes thereto included elsewhere in this Quarterly Report.

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Three Months Ended December 31, 2009

Compared to the Three Months Ended December 31, 2008

Volume

For the three months ended December 31, 2009, retail volume of home heating oil decreased by 14.2 million gallons, or 13.0%, to 95.4 million gallons, as compared to 109.6 million gallons for the three months ended December 31, 2008. An analysis of the change in the retail volume of home heating oil, which is based on management’s estimates, sampling and other mathematical calculations, is found below:

Temperatures in our geographic areas of operations for the three months ended December 31, 2009 were 5.0% warmer than the three months ended December 31, 2008 and approximately 2.2% warmer than normal, as reported by the National Oceanic Atmospheric Administration (“NOAA”). Between December 31, 2008 and December 31, 2009, net customer attrition was 6.9%, and the above table reflects the lost volume related to this net attrition. Due to the significant increase in the price per gallon of home heating oil over the last several years, we believe that customers are using less home heating oil given similar temperatures when compared to prior periods and this decrease is reflected in the "Conservation/Other" heading in the above table.

Volume of other petroleum products for the three months ended December 31, 2009 decreased by 1.5 million gallons, or 13.1%, to 9.8 million gallons, as compared to 11.3 million gallons of other petroleum products sold during the three months ended December 31, 2008.

The percentage of heating oil volume sold to residential variable price customers increased to 41.3% for the three months ended December 31, 2009, as compared to 39.0% for the three months ended December 31, 2008. The percentage of heating oil volume sold to residential price-protected customers decreased to 44.4 % for the three months ended December 31, 2009, as compared to 46.2% for the three months ended December 31, 2008. For the three months ended December 31, 2009, sales to commercial/industrial customers decreased to 14.3% of total heating oil volume sales, as compared to 14.8% for the three months ended December 31, 2008.

Product Sales

For the three months ended December 31, 2009, product sales decreased $52.5 million, or 14.8%, to $301.8 million, as compared to $354.3 million for the three months ended December 31, 2008, due to lower home heating oil volume and lower home heating oil selling prices.

Installation and Service Sales

For the three months ended December 31, 2009, service and installation sales decreased $1.5 million, or 3.1%, to $47.1 million, as compared to $48.6 million for the three months ended December 31, 2008, due to a decline in our customer base and lower new equipment sales. We believe that consumers are generally reluctant to replace their heating systems given the current economic environment.

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Cost of Product

For the three months ended December 31, 2009, cost of product decreased $35.2 million, or 14.1%, to $214.5 million, as compared to $249.7 million for the three months ended December 31, 2008, due to a decrease in home heating oil volume sold of 13% and a decrease in home heating oil product costs.

Gross Profit—Product

The table below recalculates the Partnership’s per gallon margins and reconciles product gross profit for home heating oil and other petroleum products. We believe the change in home heating oil margins should be evaluated before the effects of increases or decreases in the fair value of derivative instruments, as we believe that realized per gallon margins should not include the impact of non-cash changes in the market value of hedges before the settlement of the underlying transaction. On that basis, home heating oil margins for the three months ended December 31, 2009 decreased by $0.0418 per gallon, or 4.5%, to $0.8820 per gallon, from $0.9238 per gallon in the three months ended December 31, 2008. Product sales and cost of product include home heating oil, other petroleum products and liquidated damages billings.

For the three months ended December 31, 2009, total product gross profit decreased by $17.3 million to $87.3 million, as compared to $104.6 million for the three months ended December 31, 2008, due to the impact of lower home heating oil volume ($13.2 million) and lower home heating oil per gallon margins ($4.0 million).

Since the beginning of the heating season of fiscal 2010, home heating oil costs have risen, which has limited the Partnership’s ability to expand its margins. During the beginning of the heating season of fiscal 2009, home heating oil product costs declined, which largely contributed to the Partnership’s ability to expand its home heating oil margins during this period, as wholesale prices decreased more rapidly than retail selling prices.

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(Increase) Decrease in the Fair Value of Derivative Instruments

During the three months ended December 31, 2009, the increase in the fair value of derivative instruments resulted in the recording of a $3.4 million credit due to the expiration of certain hedged positions or their realization to cost of product (a $3.5 million credit) and a decrease in the market value for unexpired hedges (a $0.1 million charge).

During the three months ended December 31, 2008, the decrease in the fair value of derivative instruments resulted in the recording of a $36.9 million charge due to the expiration of certain hedged positions or their realization to cost of product (a $9.6 million credit), and a decrease in the market value for unexpired hedges (a $46.5 million charge).

Cost of Installations and Service

During the three months ended December 31, 2009, cost of installations and service decreased $3.1 million, or 6.4%, to $45.7 million, as compared to $48.8 million for the three months ended December 31, 2008, due to the decline in installation sales, lower vehicle fuel expense and management’s efforts to reduce costs in line with net customer attrition. Management views the service and installation department on a combined basis because many expenses cannot be separated or allocated to either service or installation billings. Many overhead functions and direct expenses such as service technician time cannot be precisely allocated.

Installation costs were $15.4 million, or 83.6% of installation sales during the three months ended December 31, 2009, and were $16.5 million, or 86.7% of installation sales during the three months ended December 31, 2008. Service expenses decreased to $30.3 million, or 105.7% of service sales during the three months ended December 31, 2009, from $32.3 million in the three months ended December 31, 2008, or 109.3% of sales. For the three months ended December 31, 2009, a net gross profit from service and installation of $1.4 million was generated, as compared to a net gross loss of $0.2 million for the three months ended December 31, 2008.

Delivery and Branch Expenses

For the three months ended December 31, 2009, delivery and branch expenses decreased $6.8 million, or 10.7%, to $56.8 million, as compared to $63.6 million for the three months ended December 31, 2008. Bad debt expense declined by $0.7 million due to the decline in total sales of 13.4%, and vehicle fuels declined by $1.5 million due to the decline in fuel costs. Insurance expense was lower by $3.1 million due to a decline in the cost of the Partnership’s weather hedge ($0.9 million) and improved claims experience ($2.2 million). Delivery and branch expenses were also favorably impacted by the decline in home heating oil volume of 13.0%.

Depreciation and Amortization

For the three months ended December 31, 2009, depreciation and amortization expenses declined by $2.5 million, or 41.5%, to $3.5 million, as compared to $6.0 million for the three months ended December 31, 2008.

Amortization expense was lower by $2.3 million, as acquisitions from 1999 with a 10 year life became fully amortized in fiscal 2009.

General and Administrative Expenses

For the three months ended December 31, 2009, general and administrative expenses were $5.1 million, slightly less when compared to $5.3 million for the three months ended December 31, 2008.

Operating Income (Loss)

For the three months ended December 31, 2009, operating income increased $34.0 million to $26.6 million, from a loss of $7.4 million for the three months ended December 31, 2008, as a decrease in product gross profit of $17.3 million was more than offset by a favorable change in the fair value of derivative instruments of $40.2 million and lower operating costs (net service, delivery, general and administrative) of $11.0 million.

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Interest Expense

For the three months ended December 31, 2009, interest expense decreased by $0.8 million, or 14.9 % to $4.3 million as compared to $5.1 million for the three months ended December 31, 2008. During fiscal 2009, the Partnership repurchased $40.3 million face value of its 10.25% Senior Notes which lowered average long-term debt outstanding by $30.6 million and corresponding interest expense by $1.0 million. Bank charges increased by $0.3 million due to an increase in letter of credit fees.

Interest Income

For the three months ended December 31, 2009, interest income decreased $0.7 million, or 63.9%, to $0.4 million, as compared to $1.1 million for the three months ended December 31, 2008, due to lower returns, lower invested cash balances, and lower finance charge income on past due accounts receivables balances.

Amortization of Debt Issuance Costs

For the three months ended December 31, 2009, amortization of debt issuance costs increased $0.1 million, or 10.8% to $0.7 million, as compared to $0.6 million for the three months ended December 31, 2008.

Gains on Bond Repurchase

During the three months ended December 31, 2008, the Partnership repurchased $10.0 million face value of its 10.25% Senior Notes due February 2013 at an average price of $64 per $100 of principal plus accrued interest. The Partnership recorded a gain of $3.5 million. The Partnership did not repurchase any of its notes during the three months ended December 31, 2009.

Income Tax Expense (Benefit)

For the three months ended December 31, 2009 income tax expense increased $10.5 million, to a $10.1 million expense, from a $0.4 million benefit for the three months ended December 31, 2008. This increase is due primarily to the $30.4 million increase in the Income (loss) before income taxes for 2009 versus 2008. In addition, due to the Partnership having a full valuation allowance as of December 31, 2008, any deferred tax benefits from the loss before income taxes for the three months ended December 31, 2008 were fully offset by the valuation allowance, leaving only a current tax benefit. As much of the valuation allowance was released as of September 30, 2009, the tax expense for the three months ended December 31, 2009 consists of a both $0.8 million current tax expense and a $9.3 million deferred tax expense.

Net Income (Loss)

For the three months ended December 31, 2009, the Partnership generated net income of $ 12.0 million, as compared to a net loss of $8.0 million for the three months ended December 31, 2008. This increase in net income of $ 20.0 million was attributable to an increase in operating income of $34.0 million which was reduced by an increase in income tax expense of $10.5 million. During the three months ended December 31, 2008, the Partnership’s recorded a gain of $3.5 million from repurchasing $10.0 million face value of its 10.25% Senior Notes, which positively impacted net income in that period.

Adjusted EBITDA

For the three months ended December 31, 2009, Adjusted EBITDA decreased by $8.8 million to $26.7 million, as compared to $35.5 million for the three months ended December 31, 2008, as a reduction in delivery and branch expenses was more than offset by the decline in home heating oil volume and home heating oil margins.

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