10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2017

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                          to                         

Commission File Number: 001-14129

STAR GAS PARTNERS, L.P.

(Exact name of registrants as specified in its charters)

Delaware	06-1437793
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
9 West Broad Street Stamford, Connecticut	06902
(Address of principal executive office)

(203) 328-7310

(Registrant’s telephone number, including area code)

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

Indicate by check mark whether the registrant (1) has 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) has been subject to such filing requirements for the past 90 days.    Yes  ☒    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 registrant is a large accelerated filer, accelerated filer, non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer	☐	Accelerated filer	☒
Non-accelerated filer	☐	Smaller reporting company	☐
		Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act).    Yes  ☐    No  ☒

At July 31, 2017, the registrant had 55,887,832 Common Units outstanding.

STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

INDEX TO FORM 10-Q

	Page
Part I Financial Information
Item 1 - Condensed Consolidated Financial Statements
Condensed Consolidated Balance Sheets as of June  30, 2017 (unaudited) and September 30, 2016		3
Condensed Consolidated Statements of Operations (unaudited) for the three and nine months ended June 30, 2017 and June 30, 2016		4
Condensed Consolidated Statements of Comprehensive Income (Loss) (unaudited) for the three and nine months ended June 30, 2017 and June 30, 2016		5
Condensed Consolidated Statement of Partners’ Capital (unaudited) for the nine months ended June 30, 2017		6
Condensed Consolidated Statements of Cash Flows (unaudited) for the nine months ended June 30, 2017 and June 30, 2016		7
Notes to Condensed Consolidated Financial Statements (unaudited)		8-19
Item  2 - Management’s Discussion and Analysis of Financial Condition and Results of Operations		20-35
Item 3 - Quantitative and Qualitative Disclosures About Market Risk		35
Item 4 - Controls and Procedures		36
Part II Other Information:
Item 1 - Legal Proceedings		36
Item 1A - Risk Factors		37
Item 2 - Unregistered Sales of Equity Securities and Use of Proceeds		37
Item 6 - Exhibits		38
Signatures		39

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Part I. FINANCIAL INFORMATION

Item 1. Condensed Consolidated Financial Statements

STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

	June 30,			September 30,
(in thousands)	2017			2016
	(unaudited)
ASSETS
Current assets
Cash and cash equivalents	$	94,574		$	139,188
Receivables, net of allowance of $6,577 and $4,419, respectively		116,646			78,650
Inventories		42,422			45,894
Fair asset value of derivative instruments		—			3,987
Prepaid expenses and other current assets		24,409			27,139
Total current assets		278,051			294,858
Property and equipment, net		74,491			70,410
Goodwill		215,262			212,760
Intangibles, net		94,520			97,656
Deferred tax assets, net		255			5,353
Restricted cash		250			—
Investments (1)		11,686			—
Deferred charges and other assets, net		9,782			11,074
Total assets	$	684,297		$	692,111
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities
Accounts payable	$	20,354		$	25,690
Fair liability value of derivative instruments		4,760			2,285
Current maturities of long-term debt		10,000			16,200
Accrued expenses and other current liabilities		130,776			103,855
Unearned service contract revenue		55,759			56,971
Customer credit balances		40,340			84,921
Total current liabilities		261,989			289,922
Long-term debt		68,155			75,441
Other long-term liabilities		25,082			25,255
Partners’ capital
Common unitholders		349,554			322,771
General partner		(672	)		(516	)
Accumulated other comprehensive loss, net of taxes		(19,811	)		(20,762	)
Total partners’ capital		329,071			301,493
Total liabilities and partners’ capital	$	684,297		$	692,111

(1) See Note 2 – Investments

See accompanying notes to condensed consolidated financial statements.

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STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(in thousands, except per unit data - unaudited)	2017			2016			2017			2016
Sales:
Product	$	158,531		$	156,229		$	950,307		$	813,519
Installations and services		67,270			61,965			191,664			185,755
Total sales		225,801			218,194			1,141,971			999,274
Cost and expenses:
Cost of product		104,268			103,568			592,802			473,534
Cost of installations and services		58,224			53,272			183,137			175,042
(Increase) decrease in the fair value of derivative instruments		3,135			(11,283	)		7,026			(20,071	)
Delivery and branch expenses		67,640			64,052			240,987			218,755
Depreciation and amortization expenses		7,418			6,468			20,705			19,959
General and administrative expenses		6,235			6,017			18,144			17,525
Finance charge income		(1,308	)		(945	)		(3,288	)		(2,480	)
Operating income (loss)		(19,811	)		(2,955	)		82,458			117,010
Interest expense, net		(1,619	)		(1,731	)		(5,118	)		(5,481	)
Amortization of debt issuance costs		(336	)		(307	)		(972	)		(934	)
Income (loss) before income taxes		(21,766	)		(4,993	)		76,368			110,595
Income tax expense (benefit)		(8,434	)		(1,755	)		31,721			46,566
Net income (loss)	$	(13,332	)	$	(3,238	)	$	44,647		$	64,029
General Partner’s interest in net income (loss)		(79	)		(19	)		259			362
Limited Partners’ interest in net income (loss)	$	(13,253	)	$	(3,219	)	$	44,388		$	63,667
Basic and diluted income (loss) per Limited Partner Unit (1):	$	(0.24	)	$	(0.06	)	$	0.70		$	0.95
Weighted average number of Limited Partner units outstanding:
Basic and Diluted		55,888			57,188			55,888			57,237

(1) See Note 13 Earnings Per Limited Partner Unit.

See accompanying notes to condensed consolidated financial statements.

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STAR GAS PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(in thousands - unaudited)	2017			2016			2017			2016
Net income (loss):	$	(13,332	)	$	(3,238	)	$	44,647		$	64,029
Other comprehensive income:
Unrealized gain on pension plan obligation (1)		532			647			1,598			1,943
Tax effect of unrealized gain on pension plan		(215	)		(267	)		(647	)		(802	)
Total other comprehensive income		317			380			951			1,141
Total comprehensive income (loss)	$	(13,015	)	$	(2,858	)	$	45,598		$	65,170

(1) This item is included in the computation of net periodic pension cost.    

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

	Number of Units										Accum. Other			Total
(in thousands - unaudited)	Common		General Partner		Common			General Partner			Comprehensive Income (Loss)			Partners’ Capital
Balance as of September 30, 2016		55,888		326	$	322,771		$	(516	)	$	(20,762	)	$	301,493
Net income		—		—		44,388			259			—			44,647
Unrealized gain on pension plan obligation		—		—		—			—			1,598			1,598
Tax effect of unrealized gain on pension plan		—		—		—			—			(647	)		(647	)
Distributions		—		—		(17,605	)		(415	)		—			(18,020	)
Balance as of June 30, 2017		55,888		326	$	349,554		$	(672	)	$	(19,811	)	$	329,071

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

	Nine Months Ended June 30,
(in thousands - unaudited)	2017			2016
Cash flows provided by (used in) operating activities:
Net income	$	44,647		$	64,029
Adjustment to reconcile net income to net cash provided by (used in) operating activities:
(Increase) decrease in fair value of derivative instruments		7,026			(20,071	)
Depreciation and amortization		21,677			20,893
Provision (recovery) for losses on accounts receivable		2,261			(140	)
Change in deferred taxes		4,451			13,299
Changes in operating assets and liabilities:
(Increase) decrease in receivables		(40,524	)		647
Decrease in inventories		3,761			13,402
Decrease in other assets		3,443			968
Decrease in accounts payable		(3,468	)		(2,173	)
Decrease in customer credit balances		(45,757	)		(2,026	)
Increase in other current and long-term liabilities		25,693			21,357
Net cash provided by operating activities		23,210			110,185
Cash flows provided by (used in) investing activities:
Capital expenditures		(9,348	)		(7,230	)
Proceeds from sales of fixed assets		171			303
Purchase of investments (1)		(11,538	)		—
Acquisitions		(14,504	)		(8,829	)
Net cash used in investing activities		(35,219	)		(15,756	)
Cash flows used in financing activities:
Term loan repayment		(13,700	)		(5,000	)
Distributions		(18,020	)		(17,097	)
Unit repurchases		—			(707	)
Customer retainage payments		(575	)		(680	)
Payments of debt issuance costs		(60	)		(297	)
Net cash used in financing activities		(32,355	)		(23,781	)
Net (decrease) increase in cash, cash equivalents, and restricted cash		(44,364	)		70,648
Cash, cash equivalents, and restricted cash at beginning of period		139,188			100,508
Cash, cash equivalents, and restricted cash at end of period	$	94,824		$	171,156

(1) See Note 2 – Investments

See accompanying notes to condensed consolidated financial statements.

7

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 full service provider specializing in the sale of home heating products and services to residential and commercial customers. The Partnership also services and sells heating and air conditioning equipment to its home heating oil and propane customers and to a lesser extent, provides these offerings to customers outside of our home heating oil and propane customer base. In certain of our marketing areas, we provide home security and plumbing services primarily to our home heating oil and propane customer base. We also sell diesel fuel, gasoline and home heating oil on a delivery only basis. These products and services are offered through our home heating oil and propane locations. The Partnership has one reportable segment for accounting purposes. We are the nation’s largest retail distributor of home heating oil based upon sales volume. Including our propane locations, we serve customers in the more northern and eastern states within the Northeast, Central and Southeast U.S. regions.

The Partnership is organized as follows:

• The Partnership is a master limited partnership, which as of June 30, 2017, had outstanding 55.9 million Common Units (NYSE: “SGU”), representing 99.4% limited partner interest in Star Gas Partners, and 0.3 million general partner units, representing 0.6% general partner interest in Star Gas Partners. The general partner of the Partnership 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”).

• The Partnership owns 100% of Star Acquisitions, Inc., a Minnesota corporation (“SA”) that owns 100% of Petro Holdings, Inc., a Minnesota corporation (“Petro”) and 100% of Woodbury Insurance Co., Inc., a Connecticut captive insurance corporation formed in July 2016 to insure large deductibles for certain insurance policies carried by Petro. SA and its subsidiaries are subject to Federal and state corporate income taxes. The Partnership’s operations are conducted through Petro and its subsidiaries. Petro is primarily a Northeast, Central and Southeast region retail distributor of home heating oil and propane that as of June 30, 2017, served approximately 441,000 full-service residential and commercial home heating oil and propane customers. Petro also sold diesel fuel, gasoline and home heating oil to approximately 73,000 customers on a delivery only basis. We installed, maintained, and repaired heating and air conditioning equipment and to a lesser extent provided these services outside our customer base including 14,900 service contracts for natural gas and other heating systems. In addition, we provided home security and plumbing to approximately 29,100 customers.

• Petroleum Heat and Power Co., Inc., a Minnesota corporation (“PH&P”) is a 100% owned subsidiary of the Partnership. PH&P is the borrower and the Partnership is the guarantor of the third amended and restated credit agreement’s $100 million five-year senior secured term loan and the $300 million ($450 million during the heating season of December through April of each year) revolving credit facility, both due July 30, 2020. (See Note 9—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 Gas Partners 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 and cash flows for the nine month period ended June 30, 2017, 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 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 and should be read in conjunction with the financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended September 30, 2016.

8

Comprehensive Income (Loss)

Comprehensive income (loss) is comprised of net income (loss) and other comprehensive income (loss). Other comprehensive income (loss) consists of the unrealized gain (loss) amortization on the Partnership’s pension plan obligation for its two frozen defined benefit pension plans and the corresponding tax effect.

Cash, cash equivalents, and restricted cash

At June 30, 2017, the $94.8 million of cash, cash equivalents, and restricted cash on the condensed consolidated statement of cash flows is composed of $94.6 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.

Investments

The investments are held by our captive insurance company in an irrevocable trust as collateral for workers’ compensation and automobile liability claims incurred and expected to be incurred in fiscal 2017. The collateral is required by a third party insurance carrier that insures per claim amounts above a set deductible. 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, the collateral is not expected to be used to pay obligations within the next twelve months.

Investments are currently comprised of $10.3 million of Level 1 debt securities and $1.4 million of mutual funds measured at net asset value.

Weather Hedge Contract

To partially mitigate the effect of weather on cash flows, the Partnership 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.

For fiscal years 2016 and 2017, the Partnership had weather hedge contracts that cover the five month period from November 1, through March 31, taken as a whole, for each respective fiscal year. The ultimate amount due to the Partnership (if any) was based on the entire five month accumulated calculation for the hedge period and had a maximum payout of $12.5 million for each respective fiscal year. In accordance with ASC 815-45-15, as of December 31, 2015, the Partnership recorded a credit of $12.5 million during fiscal 2016 under this contract that reduced delivery and branch expenses. No credit was recorded during the nine months ended June 30, 2017.

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

As of June 30, 2017, we had $0.2 million and $17.4 million balances 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. Based on the borrowing rates currently available to the Partnership for long-term financing of a similar maturity, the fair value of the NETTI Fund withdrawal liability as of June 30, 2017 was $22.2 million. 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

In April 2015, the FASB issued Accounting Standards Update (“ASU”) No. 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The update requires debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability instead of being presented as an asset. The Partnership retrospectively adopted the ASU effective December 31, 2016. As a result of the adoption, certain prior year balances (September 30, 2016) changed to conform to the current year presentation as follows: deferred charges and other assets, net decreased from $11.9 million to $11.1 million and long-term debt decreased from $76.3 million to $75.4 million.

9

In September 2015, the FASB issued ASU No. 2015-16, Simplifying the Accounting for Measurement-Period Adjustments, which requires an acquiring entity to recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The acquiring entity is required to record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. In addition, the acquiring entity is to present separately on the face of its income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods as if the adjustment to the provisional amounts had been recognized as of the acquisition date. The Partnership adopted the ASU effective December 31, 2016. The adoption of ASU No. 2015-16 did not have an impact on the Partnership’s consolidated financial statements and related disclosures.

In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flow (Topic 230): Restricted cash. The update requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The Partnership adopted the ASU effective December 31, 2016. The adoption of ASU No. 2016-18 did not have a material impact on the Partnership’s consolidated financial statements and related disclosures.

Recently Issued Accounting Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The FASB has also issued several updates to ASU 2014-09. This ASU will replace most existing revenue recognition guidance in GAAP when it becomes effective. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted beginning in the first quarter of fiscal 2018. The standard permits the use of either the retrospective or cumulative effect transition method. The Partnership is in the process of evaluating the effect that ASU 2014-09 will have on its revenue streams, consolidated financial statements and related disclosures. The Partnership has not yet selected a transition method, nor does it intend to early adopt.

In July 2015, the FASB issued ASU No. 2015-11, Simplifying the Measurement of Inventory. The update changes the measurement principle for inventory from the lower of cost or market to the lower of cost and net realizable value. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2018, with early adoption permitted. The Partnership does not expect ASU No. 2015-11 to have a material impact on its consolidated financial statements and related disclosures.

In February 2016, the FASB issued ASU No. 2016-02, Leases. The update requires all leases with a term greater than twelve months to be recognized on the balance sheet by calculating the discounted present value of such leases and accounting for them through a right-of-use asset and an offsetting lease liability, and the disclosure of key information pertaining to leasing arrangements. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2020, with early adoption permitted. The Partnership does not intend to early adopt. The Partnership is continuing to evaluate the effect that ASU No. 2016-02 could have on its consolidated financial statements and related disclosures, but has not yet selected a transition method. The new guidance will materially change how we account for operating leases for office space, trucks and other equipment. Upon adoption, we expect to recognize discounted right-of-use assets and offsetting lease liabilities related to our operating leases of office space, trucks and other equipment. As of June 30, 2017, the undiscounted future minimum lease payments through 2032 for such operating leases are approximately $131.8 million, but what the range of reasonable discount rates will be at the time of adoption and what amount of leasing activity is expected between June 30, 2017, and the date of adoption, are currently unknown. For this reason we are unable to estimate the discounted right-of-use assets and lease liabilities as of the date of adoption.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments – Credit Losses. The update broadens the information that an entity should consider in developing expected credit loss estimates, eliminates the probable initial recognition threshold, and allows for the immediate recognition of the full amount of expected credit losses. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2021, with early adoption permitted in the first quarter of fiscal 2020. The Partnership is evaluating the effect that ASU No. 2016-13 will have on its consolidated financial statements and related disclosures, but has not yet determined the timing of adoption.

10

In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flow (Topic 230): Classification of Certain Cash Receipts and Cash Payments. The update addresses the issues of debt prepayment or debt extinguishment costs, settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate owned life insurance policies, distributions received from equity method investees, beneficial interests in securitization transactions, and separately identifiable cash flows and application of the predominance principle. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2016-15 to have a material impact on its consolidated financial statements and related disclosures.

In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the definition of a business. The update clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2017-01 to have a material impact on its consolidated financial statements and related disclosures.

In January 2017, the FASB issued ASU No. 2017-04, Intangibles – Goodwill and Other (Topic 230): Simplifying the test for goodwill impairment. The update simplifies how an entity is required to test goodwill for impairment. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value, but not exceed the total amount of goodwill allocated to the reporting unit. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2021, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2017-04 to have a material impact on its consolidated financial statements and related disclosures.

3) Common Unit Repurchase and Retirement

In July 2012, the Board authorized the repurchase of up to 3.0 million of the Partnership’s Common Units (“Plan III”). In July 2013, the Board authorized the repurchase of an additional 1.9 million Common Units under Plan III. 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. There is no guarantee of the exact number of units that will be purchased under the program and the Partnership may discontinue purchases at any time. The program does not have a time limit. The Board may also approve additional purchases of units from time to time in private transactions. 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.

Under the Partnership’s third amended and restated credit agreement dated July 30, 2015, in order to repurchase Common Units we must maintain Availability (as defined in the amended and restated credit agreement) of $45 million, 15.0% of the facility size of $300 million (assuming the non-seasonal aggregate commitment is in effect) 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. The Partnership was in compliance with this covenant as of June 30, 2017.

The following table shows repurchases under Plan III.

(in thousands, except per unit amounts) Period	Total Number of Units Purchased (a)		Average Price Paid per Unit (b)		Maximum Number of Units that May Yet Be Purchased
Plan III - Number of units authorized						4,894
Private transaction - Number of units authorized						2,450
						7,344
Plan III - Fiscal years 2012 to 2016 total (c)		5,137	$	5.78		2,207
Plan III - Fiscal year 2017 total		—	$	—		2,207

(a) Units were repurchased as part of a publicly announced program, except as noted in a private transaction.

(b) Amounts include repurchase costs.

(c) Includes 2.45 million common units acquired in a private transaction.

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4) Derivatives and Hedging—Disclosures and Fair Value Measurements

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 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, priced purchase commitments and internal fuel usage. The Partnership has elected not to designate its derivative instruments as hedging derivatives, but rather as economic hedges whose change in fair value is recognized in its statement of operations in the line item (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 June 30, 2017, to hedge a substantial majority of the purchase price associated with heating oil gallons anticipated to be sold to its price-protected customers, the Partnership held the following derivative instruments that settle in future months to match anticipated sales: 9.0 million gallons of swap contracts, 3.6 million gallons of call options, 5.0 million gallons of put options, and 55.0 million net gallons of synthetic call options. To hedge the inter-month differentials for its price-protected customers, its physical inventory on hand and inventory in transit, the Partnership, as of June 30, 2017, had 1.3 million gallons of long swap contracts, 53.3 million gallons of long future contracts, and 67.7 million gallons of short future contracts that settle in future months. In addition to the above, to lock-in the differential between high sulfur home heating oil and ultra low sulfur diesel, the Partnership as of June 30, 2017, had 0.4 million gallons of spread contracts (simultaneous long and short positions). To hedge its internal fuel usage and other related activities for fiscal 2017, the Partnership, as of June 30, 2017, had 6.5 million gallons of swap contracts that settle in future months.

As of June 30, 2016, to hedge a substantial majority of the purchase price associated with heating oil gallons anticipated to be sold to its price-protected customers, the Partnership held the following derivative instruments that settle in future months to match anticipated sales: 6.6 million gallons of swap contracts, 4.5 million gallons of call options, 4.1 million gallons of put options, and 60.0 million net gallons of synthetic call options. To hedge the inter-month differentials for its price-protected customers, its physical inventory on hand and inventory in transit, the Partnership, as of June 30, 2016, had 1.1 million gallons of long swap contracts, 54.0 million gallons of long future contracts, and 70.1 million gallons of short future contracts that settle in future months. In addition to the previously described hedging instruments, to lock-in the differential between high sulfur home heating oil and ultra low sulfur diesel, the Partnership as of June 30, 2016, had 0.7 million gallons of spread contracts (simultaneous long and short positions). To hedge its internal fuel usage and other related activities for fiscal 2016, the Partnership, as of June 30, 2016, had 5.9 million gallons of swap contracts that settle in future months.

The Partnership’s derivative instruments are with the following counterparties: Bank of America, N.A., Bank of Montreal, Cargill, Inc., Citibank, N.A., JPMorgan Chase Bank, N.A., Key Bank, N.A., Munich Re Trading LLC, Regions Financial Corporation, Societe Generale, and Wells Fargo Bank, N.A. The Partnership 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 Partnership generally does not receive cash collateral from its counterparties and does not restrict the use of cash collateral it maintains at counterparties. At June 30, 2017, the aggregate cash posted as collateral in the normal course of business at counterparties was $0.5 million, which was recorded in prepaid expenses and other current assets. Positions with counterparties who are also parties to our credit agreement are collateralized under that facility. As of June 30, 2017, $4.9 million of hedge positions were secured under the credit facility.

FASB ASC 820-10 Fair Value Measurements and Disclosures, 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 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 Partnership’s Level 2 derivative assets and liabilities represent the fair value of commodity 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 Partnership 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 Partnership. The Partnership’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 Partnership are based on a combination of the NYMEX published market prices and other inputs, including such factors as present value, volatility and duration.

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

(In thousands)					Fair Value Measurements at Reporting Date Using:
Derivatives Not Designated as Hedging Instruments					Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs
Under FASB ASC 815-10	Balance Sheet Location	Total			Level 1			Level 2
Asset Derivatives at June 30, 2017
Commodity contracts	Fair asset and fair liability value of derivative instruments	$	8,378		$	—		$	8,378
Commodity contracts	Long-term derivative assets included in the deferred charges and other assets, net and other long-term liabilities balances		1,096			—			1,096
Commodity contract assets at June 30, 2017		$	9,474		$	—		$	9,474
Liability Derivatives at June 30, 2017
Commodity contracts	Fair liability and fair asset value of derivative instruments	$	(13,138	)	$	—		$	(13,138	)
Commodity contracts	Cash collateral		—			—			—
Commodity contracts	Long-term derivative liabilities included in the deferred charges and other assets, net and other long-term liabilities balances		(1,232	)		—			(1,232	)
Commodity contract liabilities at June 30, 2017		$	(14,370	)	$	—		$	(14,370	)
Asset Derivatives at September 30, 2016
Commodity contracts	Fair asset and fair liability value of derivative instruments	$	11,692		$	—		$	11,692
Commodity contracts	Long-term derivative assets included in the other long-term liabilities balance		1,369			481			888
Commodity contract assets at September 30, 2016		$	13,061		$	481		$	12,580
Liability Derivatives at September 30, 2016
Commodity contracts	Fair liability and fair asset value of derivative instruments	$	(9,990	)	$	(1,603	)	$	(8,387	)
Commodity contracts	Cash collateral		—			—			—
Commodity contracts	Long-term derivative liabilities included in the other long-term liabilities balance		(565	)		(484	)		(81	)
Commodity contract liabilities at September 30, 2016		$	(10,555	)	$	(2,087	)	$	(8,468	)

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

(In thousands)									Gross Amounts Not Offset in the Statement of Financial Position
Offsetting of Financial Assets (Liabilities) and Derivative Assets (Liabilities)	Gross Assets Recognized		Gross Liabilities Offset in the Statement of Financial Position			Net Assets (Liabilities) Presented in the Statement of Financial Position			Financial Instruments		Cash Collateral Received		Net Amount
Fair asset value of derivative instruments	$	—	$	—		$	—		$	—	$	—	$	—
Long-term derivative assets included in deferred charges and other assets, net		174		(165	)		9			—		—		9
Fair liability value of derivative instruments		8,378		(13,138	)		(4,760	)		—		—		(4,760	)
Long-term derivative liabilities included in other long-term liabilities, net		922		(1,067	)		(145	)						(145	)
Total at June 30, 2017	$	9,474	$	(14,370	)	$	(4,896	)	$	—	$	—	$	(4,896	)
Fair asset value of derivative instruments	$	7,716	$	(3,729	)	$	3,987		$	—	$	—	$	3,987
Long-term derivative assets included in other long-term assets, net		888		(81	)		807			—		—		807
Fair liability value of derivative instruments		3,976		(6,261	)		(2,285	)		—		—		(2,285	)
Long-term derivative liabilities included in other long-term liabilities, net		481		(484	)		(3	)		—		—		(3	)
Total at September 30, 2016	$	13,061	$	(10,555	)	$	2,506		$	—	$	—	$	2,506

(In thousands)
The Effect of Derivative Instruments on the Statement of Operations
		Amount of (Gain) or Loss Recognized
Derivatives Not Designated as Hedging Instruments Under FASB ASC 815-10	Location of (Gain) or Loss Recognized in Income on Derivative	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016			Nine Months Ended June 30, 2017			Nine Months Ended June 30, 2016
Commodity contracts	Cost of product (a)	$	1,092	$	8,177		$	4,073		$	16,978
Commodity contracts	Cost of installations and service (a)	$	—	$	72		$	(526	)	$	848
Commodity contracts	Delivery and branch expenses (a)	$	27	$	150		$	(422	)	$	1,029
Commodity contracts	(Increase) / decrease in the fair value of derivative instruments (b)	$	3,135	$	(11,283	)	$	7,026		$	(20,071	)

(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.

5) Inventories

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

	June 30, 2017		September 30, 2016
Product	$	21,364	$	25,419
Parts and equipment		21,058		20,475
Total inventory	$	42,422	$	45,894

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6) Property and Equipment

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

	June 30, 2017		September 30, 2016
Property and equipment	$	195,181	$	184,079
Less: accumulated depreciation		120,690		113,669
Property and equipment, net	$	74,491	$	70,410

7) Business Combinations

Through the third quarter of fiscal 2017, the Partnership acquired three heating oil dealers, a propane dealer and a plumbing service provider for an aggregate purchase price of approximately $16.0 million; $14.5 million in cash and $1.5 million of deferred liabilities (including $0.6 million of contingent consideration). The gross purchase price was allocated $9.3 million to intangible assets, $2.5 million to goodwill, $5.0 million to fixed assets and received credit for a negative working capital position of $0.8 million. The acquired companies’ operating results are included in the Partnership’s consolidated financial statements starting on their respective acquisition dates, and are not material to the Partnership’s financial condition, results of operations, or cash flows.

8) Goodwill and Intangibles, net

Goodwill

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

Balance as of September 30, 2016	$	212,760
Fiscal year 2017 business combinations		2,502
Balance as of June 30, 2017	$	215,262

Intangibles, net

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

	June 30, 2017						September 30, 2016
	Gross						Gross
	Carrying		Accum.				Carrying		Accum.
	Amount		Amortization		Net		Amount		Amortization		Net
Customer lists	$	334,605	$	261,017	$	73,588	$	327,388	$	250,427	$	76,961
Trade names and other intangibles		29,210		8,278		20,932		27,134		6,439		20,695
Total	$	363,815	$	269,295	$	94,520	$	354,522	$	256,866	$	97,656

Amortization expense for intangible assets was $12.4 million for the nine months ended June 30, 2017, compared to $11.5 million for the nine months ended June 30, 2016.

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9) Long-Term Debt and Bank Facility Borrowings

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

	June 30,				September 30,
	2017				2016
	Carrying				Carrying
	Amount		Fair Value (a)		Amount		Fair Value (a)
Revolving Credit Facility Borrowings	$	—	$	—	$	—	$	—
Senior Secured Term Loan (b)	$	78,155	$	78,800	$	91,641	$	92,500
Total debt	$	78,155	$	78,800	$	91,641	$	92,500
Total short-term portion of debt	$	10,000	$	10,000	$	16,200	$	16,200
Total long-term portion of debt	$	68,155	$	68,800	$	75,441	$	76,300

(a) The face amount of the Partnership’s variable rate long-term debt approximates fair value.

(b) Carrying amounts are net of unamortized debt issuance costs of $0.6 million as of June 30, 2017, and $0.9 million as of September 30, 2016.

On July 30, 2015, the Partnership entered into a third amended and restated asset-based credit agreement with a bank syndicate comprised of thirteen participants, which enables the Partnership to borrow up to $300 million ($450 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 $100 million five-year senior secured term loan (the “Term Loan”), allows for the issuance of up to $100 million in letters of credit, and has a maturity date of July 30, 2020.

The Partnership can increase the revolving credit facility size by $100 million without the consent of the bank group. However, the bank group is not obligated to fund the $100 million increase. If the bank group elects not to fund the increase, the Partnership can add additional lenders to the group, with the consent of the Agent (as defined in the credit agreement), which shall not be unreasonably withheld. Obligations under the third amended and restated credit facility are guaranteed by the Partnership and its subsidiaries and are secured by liens on substantially all of the Partnership’s assets including accounts receivable, inventory, general intangibles, real property, fixtures and equipment.

All amounts outstanding under the third amended and restated revolving credit facility become due and payable on the facility termination date of July 30, 2020. The Term Loan is repayable in quarterly payments of $2.5 million, plus an annual payment equal to 25% of the annual Excess Cash Flow as defined in the agreement (an amount not to exceed $15 million annually), less certain voluntary prepayments made during the year, with final payment at maturity.

The interest rate on the third amended and restated revolving credit facility and the Term Loan is based on a margin over LIBOR or a base rate. At June 30, 2017, the effective interest rate on the Term Loan was approximately 4.01%.

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 third amended and restated credit agreement requires the Partnership to meet certain financial covenants, including a fixed charge coverage ratio (as defined in the credit agreement) of not less than 1.1 as long as the Term Loan is outstanding or revolving credit facility availability is less than 12.5% of the facility size. In addition, as long as the Term Loan is outstanding, a senior secured leverage ratio at any time cannot be more than 3.0 as calculated during the quarters ending June or September, and at any time no more than 4.5 as calculated during the quarters ending December or March.

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

At June 30, 2017, $78.8 million of the Term Loan was outstanding, no amount was outstanding under the revolving credit facility, $4.9 million of hedge positions were secured under the credit agreement, and $48.2 million of letters of credit were issued and outstanding. At September 30, 2016, $92.5 million of the Term Loan was outstanding, no amount was outstanding under the revolving credit facility, $0.3 million of hedge positions were secured under the credit agreement, and $50.6 million of letters of credit were issued and outstanding.

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At June 30, 2017, availability was $160.3 million, and the Partnership was in compliance with the fixed charge coverage ratio and the senior secured leverage ratio. At September 30, 2016, availability was $163.4 million, and the Partnership was in compliance with the fixed charge coverage ratio and the senior secured leverage ratio.

10) Income Taxes

Since Star Gas Partners is organized as a master limited partnership, it is not subject to tax at its entity level for Federal and state income tax purposes. However, Star Gas Partners’ income is derived from its corporate subsidiaries, and these entities do incur Federal and state income taxes relating to their respective corporate subsidiaries, which are reflected in these financial statements. For the corporate subsidiaries of Star Gas Partners, a consolidated Federal income tax return is filed.

Income and losses of Star Gas Partners are allocated directly to the individual partners. Even though Star Gas Partners will generate non-qualifying Master Limited Partnership income through its corporate subsidiaries, cash received by Star Gas Partners from its corporate subsidiaries is generally included in the determination of qualified Master Limited Partnership income. All or a portion of such cash could be taxable as dividend income or as a capital gain to the individual partners. This could be the case even if Star Gas Partners used the cash received from its corporate subsidiaries for purposes such as the repurchase of Common Units, other types of capital transactions, or paying its own expenses rather than for distributions to its individual partners.

The accompanying financial statements are reported on a fiscal year; however, Star Gas Partners and its corporate subsidiaries file Federal and state income tax returns on a calendar year.

The current and deferred income tax expenses (benefits) for the three and nine months ended June 30, 2017, and 2016, are as follows:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(in thousands)	2017			2016			2017		2016
Income (loss) before income taxes	$	(21,766	)	$	(4,993	)	$	76,368	$	110,595
Current tax expense (benefit)		(5,764	)		(6,759	)		27,270		33,268
Deferred tax expense (benefit)		(2,670	)	$	5,004			4,451	$	13,298
Total tax expense (benefit)	$	(8,434	)	$	(1,755	)	$	31,721	$	46,566

As of January 1, 2017, Star Acquisitions, Inc., a wholly-owned subsidiary of the Partnership, had an estimated Federal net operating loss carry forward (“NOLs”) of approximately $1.6 million. The Federal NOLs, which will expire between 2018 and 2024, are generally available to offset any future taxable income but are also subject to annual limitations of between $1.0 million and $2.2 million.

At June 30, 2017, we did not 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, Pennsylvania we have four years that are subject to examination. In the state tax jurisdictions 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.

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11) Supplemental Disclosure of Cash Flow Information

	Nine Months Ended
	June 30,
(in thousands)	2017		2016
Cash paid during the period for:
Income taxes, net	$	4,116	$	15,411
Interest	$	6,002	$	5,082
Non-cash operating activities:
Increase in interest expense—amortization of deferred charges on senior secured term loan	$	225	$	214

12) Commitments and Contingencies

On February 18, 2016, a civil action was filed in the United States District Court, District of New Jersey, entitled M. Norman Donnenfeld v. Petro Home Services, Petro Holdings Inc. and Petro, Inc., Civil Action Number 2:16-cv-00882 JMV-JBC, against Petro Home Services which is a brand name, Petro Holdings Inc. and Petro, Inc. Plaintiff alleged he did not receive expected contractual benefits under his protected price plan contract when oil prices fell and asserted various claims for relief including breach of contract, violation of the New York General Business Law and fraud. The Plaintiff also sought to have a class certified of all customers of the defendants in the United States who entered into protected price plan contracts and were denied the same contractual benefits and to be appointed to represent them. The Plaintiff sought compensatory, punitive and other damages in unspecified amounts. On May 9, 2016, the Partnership filed a motion to dismiss the complaint for lack of personal jurisdiction and failure to state a claim for relief and to strike the class action allegations. On March 24, 2017, the motion to dismiss the complaint was granted, for failure to state a claim and for lack of personal jurisdiction but Plaintiff was given 30 days to attempt to replead.

Instead of filing an amended complaint, on April 18, 2017, Plaintiff commenced a new putative class action in the United States District Court for the Eastern District of New York, entitled M. Norman Donnenfeld v. Petro, Inc., Civil Action Number 2:17-cv-02310-JFB-SIL. The new complaint names Petro, Inc. d/b/a Petro Home Services as the sole defendant. The allegations and claims in the new complaint are substantially similar to those in the prior complaint filed in the District of New Jersey. No class has yet been certified in this action. The Partnership believes the allegations lack merit and intends to vigorously defend the action; at this time we cannot assess the potential outcome or materiality of this matter.

The Partnership’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 Partnership is a defendant in various legal proceedings and litigation. The Partnership 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 Partnership’s results of operations, financial position or liquidity.

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 current and potential future claims, legal proceedings and litigation, including the above mentioned action, 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.

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13) Earnings Per Limited Partner Unit

Income per limited partner unit is computed in accordance with FASB ASC 260-10-05 Earnings Per Share, Master Limited Partnerships (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 result 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 performed, in which the Partnership’s contractual participation rights are taken into account.

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

	Three Months Ended						Nine Months Ended
Basic and Diluted Earnings Per Limited Partner:	June 30,						June 30,
(in thousands, except per unit data)	2017			2016			2017		2016
Net income (loss)	$	(13,332	)	$	(3,238	)	$	44,647	$	64,029
Less General Partner’s interest in net income		(79	)		(19	)		259		362
Net income (loss) available to limited partners		(13,253	)		(3,219	)		44,388		63,667
Less dilutive impact of theoretical distribution of earnings under FASB ASC 260-10-45-60		—			—			5,420		9,313
Limited Partner’s interest in net income (loss) under FASB ASC 260-10-45-60	$	(13,253	)	$	(3,219	)	$	38,968	$	54,354
Per unit data:
Basic and diluted net income (loss) available to limited partners	$	(0.24	)	$	(0.06	)	$	0.79	$	1.11
Less dilutive impact of theoretical distribution of earnings under FASB ASC 260-10-45-60		—			—			0.09		0.16
Limited Partner’s interest in net income (loss) under FASB ASC 260-10-45-60	$	(0.24	)	$	(0.06	)	$	0.70	$	0.95
Weighted average number of Limited Partner units outstanding		55,888			57,188			55,888		57,237

14) Subsequent Events

Quarterly Distribution Declared

In July 2017, we declared a quarterly distribution of $0.11 per unit, or $0.44 per unit on an annualized basis, on all Common Units with respect to the second quarter of fiscal 2017, payable on August 8, 2017, to holders of record on July 31, 2017. In accordance with our Partnership Agreement, the amount of distributions in excess of the minimum quarterly distribution of $0.0675, are distributed 90% to Common Unit holders and 10% to the General Partner unit holders (until certain distribution levels are met), subject to the management incentive compensation plan. As a result, $6.1 million will be paid to the Common Unit holders, $0.2 million to the General Partner unit holders (including $0.1 million of incentive distribution as provided in our Partnership Agreement) and $0.1 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.

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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 the products that we sell, the consumption patterns of our customers, our ability to obtain satisfactory gross profit margins, our ability to obtain new customers and retain existing customers, 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 current and future governmental regulations, including environmental, health, and safety regulations, the ability to attract and retain employees, customer credit worthiness, counterparty credit worthiness, marketing plans, general economic conditions and new technology. 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. Without limiting the foregoing, the words “believe,” “anticipate,” “plan,” “expect,” “seek,” “estimate,” and similar expressions are intended to identify 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. These risks and uncertainties include, but are not limited to, those set forth in this Report under the headings “Risk Factors” and “Business Strategy.” Important factors that could cause actual results to differ materially from our expectations (“Cautionary Statements”) are disclosed in this Report. 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.

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 the fiscal quarters and years unless otherwise noted. The seasonal nature of our business has resulted, on average, during the last five years, in the sale of approximately 30% of our volume of home heating oil and propane in the first fiscal quarter and 50% of our volume in the second fiscal quarter, the peak heating season. We generally realize net income in both of these quarters and net losses during the quarters ending June and September. In addition, sales volume typically fluctuates from year to year in response to variations in weather, wholesale energy prices and other factors.

Degree Days

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 daily 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 to see if a month or a year was warmer or cooler than usual. Degree days are officially observed by the National Weather Service.

Every ten years, the National Oceanic and Atmospheric Administration (“NOAA”) computes and publishes average meteorological quantities, including the average temperature for the last 30 years by geographical location, and the corresponding degree days. The latest and most widely used data covers the years from 1981 to 2010. Our calculations of “normal” weather are based on these published 30 year averages for heating degree days, weighted by volume for the locations where we have existing operations.

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Home Heating Oil Price Volatility

Volatility, which is reflected in the wholesale price of home heating oil, has a larger impact on our business when prices rise, as consumer price sensitivity to heating costs increases, often leading to increased gross customer losses. As a commodity, the price of home heating oil is generally impacted by many factors, including economic and geopolitical forces. The price of home heating oil is closely linked to the price refiners pay for crude oil, which is the principal cost component of home heating oil. The volatility in the wholesale cost of home heating oil, as measured by the New York Mercantile Exchange (“NYMEX”), for the fiscal years ending September 30, 2013, through 2017, on a quarterly basis, is illustrated in the following chart (price per gallon):

	Fiscal 2017				Fiscal 2016				Fiscal 2015				Fiscal 2014				Fiscal 2013 (1)
	Low		High		Low		High		Low		High		Low		High		Low		High
Quarter Ended
December 31	$	1.39	$	1.70	$	1.08	$	1.61	$	1.85	$	2.66	$	2.84	$	3.12	$	2.90	$	3.26
March 31		1.49		1.70		0.87		1.26		1.62		2.30		2.89		3.28		2.86		3.24
June 30		1.37		1.65		1.08		1.57		1.68		2.02		2.85		3.05		2.74		3.09
September 30		—		—		1.26		1.53		1.38		1.84		2.65		2.98		2.87		3.21

(1) Beginning April 1, 2013, the NYMEX contract specifications were changed from high sulfur home heating oil to ultra low sulfur diesel. Ultra low sulfur diesel is similar in composition to ultra low sulfur home heating oil.

Impact on Liquidity of Wholesale Product Cost Volatility

Our liquidity is adversely impacted in times of increasing wholesale product costs, as we must use more cash to fund our hedging requirements and a portion of the increased levels of accounts receivable and inventory. Our liquidity is also adversely impacted at times by sudden and sharp decreases in wholesale product costs due to the increased margin requirements for futures contracts and collateral requirements for options and swaps that we use to manage market risks.

Weather Hedge Contract

Weather conditions have a significant impact on the demand for home heating oil and propane because customers depend on these products principally for space heating purposes. Actual weather conditions may vary substantially from year to year, significantly affecting the Partnership’s financial performance. To partially mitigate the adverse effect of warm weather on cash flow, we have used weather hedging contracts for a number of years.

The Partnership has weather hedge contracts for fiscal years 2016, 2017, 2018 and 2019 with several providers. Under these contracts, the Partnership is entitled to a payment if the total number of degree days within the hedge period is less than the ten year average. The “payment thresholds,” or strikes, are set at various levels. In addition, for fiscal years 2018 and 2019, the Partnership will be required to make a payment if degree days exceed the ten year average. The hedge period runs from November 1 through March 31, taken as a whole, for each respective fiscal year. For each fiscal year, the maximum that the Partnership can receive is $12.5 million and for fiscal years 2018 and 2019, the maximum that the Partnership can pay is $5.0 million. During the first quarter of fiscal 2016, the Partnership recorded a credit of $12.5 million under this contract that reduced delivery and branch expenses. This amount was subsequently collected in April 2016. The Partnership did not realize any benefit under its weather hedge contract for the nine months ended June 30, 2017.

Per Gallon Gross Profit Margins

We believe home heating oil and propane 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 a ceiling price or fixed price for home heating oil over a fixed period of time, generally twelve to twenty-four months (“price-protected” customers). When these price-protected customers agree to purchase home heating oil from us for the next heating season, we 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 may be required to obtain additional volume at unfavorable costs. In addition, should actual usage in any month be less than the hedged volume, our hedging costs and losses could be greater, thus reducing expected margins.

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Derivatives

FASB ASC 815-10-05 Derivatives and Hedging requires 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 guidance, changes in fair value are recognized in other comprehensive income until the forecasted hedged item is recognized in earnings. We have elected not to designate our derivative instruments as hedging instruments under this guidance and, as a result, the changes in fair value of the derivative instruments are recognized in our statement of operations. Therefore, we experience volatility in earnings as outstanding derivative instruments are marked to market and non-cash gains and losses are recorded prior to the sale of the commodity to the customer. The volatility in any given period related to unrealized non-cash gains or losses on derivative instruments can be significant to our overall results. However, we ultimately expect those gains and losses to be offset by the cost of product when purchased.

Income Taxes

Book Versus Tax Deductions

The amount of cash flow that we generate in any given year depends upon a variety of factors including the amount of cash income taxes that our corporate subsidiaries are required to pay, which will increase as tax depreciation and amortization decreases. The amount of depreciation and amortization that we deduct for book (i.e., financial reporting) purposes will differ from the amount that our subsidiaries can deduct for tax purposes. The table below compares the estimated depreciation and amortization for book purposes to the amount that our subsidiaries expect to deduct for tax purposes based on currently owned assets. Our subsidiaries file their tax returns based on a calendar year. The amounts below are based on our September 30 fiscal year.

Estimated Depreciation and Amortization Expense

	Book		Tax
2017	$	28,872	$	28,592
2018		26,813		24,135
2019		23,816		20,052
2020		20,088		16,863
2021		15,502		14,620
2022		12,216		12,926

Non-Deductible Partnership Expenses

The Partnership incurs certain expenses at the Partnership level that are not deductible for Federal or state income tax purposes by our corporate subsidiaries. As a result, our effective tax rate could differ from the statutory rate that would be applicable if such expenses were deductible.

Customer Attrition

We measure net customer attrition on an ongoing basis for our full service residential and commercial home heating oil and propane customers. Net customer attrition is the difference between gross customer losses and customers added through marketing efforts. Customers added through acquisitions are not included in the calculation of gross customer gains. However, additional customers that are obtained through marketing efforts or lost at newly acquired businesses are included in these calculations. Customer attrition percentage calculations include customers added through acquisitions in the denominators of the calculations on a weighted average basis. Gross customer losses are the result of a number of factors, including price competition, move-outs, credit losses and conversion 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. 

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Customer gains and losses of home heating oil and propane customers

	Fiscal Year Ended
	2017							2016							2015
					Net							Net							Net
	Gross Customer				Gains /			Gross Customer				Gains /			Gross Customer				Gains /
	Gains		Losses		(Attrition)			Gains		Losses		(Attrition)			Gains		Losses		(Attrition)
First Quarter		24,300		19,100		5,200			22,800		24,200		(1,400	)		27,400		23,100		4,300
Second Quarter		13,200		16,400		(3,200	)		13,700		19,300		(5,600	)		16,000		18,200		(2,200	)
Third Quarter		8,000		12,700		(4,700	)		7,400		14,100		(6,700	)		7,400		14,000		(6,600	)
Fourth Quarter		—		—		—			11,400		21,200		(9,800	)		13,900		17,900		(4,000	)
Total		45,500		48,200		(2,700	)		55,300		78,800		(23,500	)		64,700		73,200		(8,500	)

Customer gains (attrition) as a percentage of home heating oil and propane customer base

	Fiscal Year Ended
	2017									2016									2015
							Net									Net									Net
	Gross Customer						Gains /			Gross Customer						Gains /			Gross Customer						Gains /
	Gains			Losses			(Attrition)			Gains			Losses			(Attrition)			Gains			Losses			(Attrition)
First Quarter		5.6	%		4.4	%		1.2	%		5.0	%		5.3	%		(0.3	%)		6.2	%		5.2	%		1.0	%
Second Quarter		3.0	%		3.7	%		(0.7	%)		3.0	%		4.2	%		(1.2	%)		3.6	%		4.1	%		(0.5	%)
Third Quarter		1.8	%		2.9	%		(1.1	%)		1.6	%		3.1	%		(1.5	%)		1.7	%		3.1	%		(1.4	%)
Fourth Quarter		—	%		—	%		—	%		2.5	%		4.6	%		(2.1	%)		3.1	%		4.0	%		(0.9	%)
Total		10.4	%		11.0	%		(0.6	%)		12.1	%		17.2	%		(5.1	%)		14.6	%		16.4	%		(1.8	%)

For the nine months ended June 30, 2017, the Partnership’s net customer attrition improved by 11,000 accounts as we lost 2,700 accounts (net), or 0.6%, of our home heating oil and propane customer base, compared to 13,700 accounts lost (net), or 3.0% of our home heating oil and propane customer base, during the prior year’s comparable period. (The net customer attrition rate improved by 2.4 %.) Our gross customer gains were 1,600 higher than the prior year’s comparable period and more importantly, our gross customer losses were lower by 9,400 accounts. The majority of the improvement in fiscal 2017 (6,600 accounts, net) occurred during the first fiscal quarter due to a return to more normal weather conditions, as we believe that customers did not see a need during the prior fiscal year first quarter (an unusually warm period) for the higher level of service that we can provide, and competitive margin management. During the second and third quarters of fiscal 2017, net customer attrition improved by 4,400 compared to the prior year periods. Gross customer gains were higher by 100 accounts, and gross customer losses improved by 4,300 accounts. We believe that the lower level of gross customer losses is the result of our increased expenditures in the customer experience area and our focus on customer satisfaction and retention efforts.

For the nine months ended June 30, 2017, we estimate that we lost 0.9% of our home heating oil accounts to natural gas conversions versus 1.0% for the nine months ended June 30, 2016 and 1.3% for the nine months ended June 30, 2015. Losses to natural gas in our footprint for the heating oil industry as a whole could be greater or less than the Partnership’s estimates. Conversions to natural gas may continue as it remains less expensive than home heating oil on an equivalent BTU basis.

Consolidated Results of Operations

The following is a discussion of the consolidated 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 June 30, 2017

Compared to the Three Months Ended June 30, 2016

Volume

For the three months ended June 30, 2017, the retail volume of home heating oil and propane sold decreased by 4.2 million gallons, or 9.4%, to 40.5 million gallons, compared to 44.7 million gallons for the three months ended June 30, 2016. For those locations where the Partnership had existing operations during both periods, which we sometimes refer to as the “base business” (i.e., excluding acquisitions), temperatures (measured on a heating degree day basis) for the three months ended June 30, 2017 were 19.7% warmer than the three months ended June 30, 2016 and 17.6% warmer than normal, as reported by NOAA. For the twelve months ended June 30, 2017, net customer attrition for the base business was 2.8%. The impact of fuel conservation, along with any period-to-period differences in delivery scheduling, the timing of accounts added or lost during the fiscal years, equipment efficiency, and other volume variances not otherwise described are included in the chart below under the heading “Other.” While temperatures for the three months ended June 30, 2017 were warmer than the prior year’s comparable quarter, we believe the impact on volume is much less during this springtime period than during the winter heating season. In addition, only a portion of the Partnership’s customer base normally receives a delivery during the third fiscal quarter which mutes the impact of any volume change due to a change in temperatures. An analysis of the change in the retail volume of home heating oil and propane sold, which is based on management’s estimates, sampling and other mathematical calculations and certain assumptions, is found below:

(in millions of gallons)	Heating Oil and Propane
Volume - Three months ended June 30, 2016		44.7
Acquisitions		0.8
Impact of warmer temperatures		(9.2	)
Net customer attrition		(1.1	)
Other		5.3
Change		(4.2	)
Volume - Three months ended June 30, 2017		40.5

The following chart sets forth the percentage by volume of total home heating oil sold to residential variable-price customers, residential price-protected customers and commercial/industrial/other customers for the three months ended June 30, 2017 compared to the three months ended June 30, 2016:

	Three Months Ended
Customers	June 30, 2017			June 30, 2016
Residential Variable		40.2	%		40.4	%
Residential Price-Protected		46.9	%		47.5	%
Commercial/Industrial/Other		12.9	%		12.1	%
Total		100.0	%		100.0	%

Volume of other petroleum products sold increased slightly to 27.5 million gallons for the three months ended June 30, 2017, compared to 27.2 million gallons for the three months ended June 30, 2016, as a decline in the base business of 0.3 million gallons, or 1.2%, was more than offset by the impact of acquisitions which contributed 0.6 million gallons.

Product Sales

For the three months ended June 30, 2017, product sales increased $2.3 million, or 1.5%, to $158.5 million, compared to $156.2 million for the three months ended June 30, 2016, as an increase in wholesale product costs of $0.0929 per gallon, or 6.5%, and an increase in per gallon margins more than offset a decline in total volume of 5.4%.

Installations and Services

For the three months ended June 30, 2017, installation and service sales increased $5.3 million, or 8.6%, to $67.3 million, compared to $62.0 million for the three months ended June 30, 2016, primarily due to higher air conditioning installation and service, sales growth in other services and acquisitions.

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Cost of Product

For the three months ended June 30, 2017, cost of product increased $0.7 million, or 0.7%, to $104.3 million, compared to $103.6 million for the three months ended June 30, 2016, reflecting a $0.0929 per gallon, or 6.5%, increase in wholesale product costs, somewhat offset by a 5.4% decline in total volume.

Gross Profit—Product

The table below calculates the Partnership’s per gallon margins and reconciles product gross profit for home heating oil and propane and other petroleum products. The third quarter of the Partnership’s fiscal year is a non-heating season quarter and thus the per gallon margins realized are not as impactful on the Partnership’s annual results as the per gallon margins realized during the heating season, due to the low volume sold in the third fiscal quarter. We believe the change in home heating oil and propane 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 and propane margins for the three months ended June 30, 2017 increased by $0.1382 per gallon, to $1.1455 per gallon, from $1.0073 per gallon during the three months ended June 30, 2016. Product sales and cost of product include home heating oil, propane, other petroleum products, and liquidated damages billings.

	Three Months Ended
	June 30, 2017				June 30, 2016
Home Heating Oil and Propane	Amount (in millions)		Per Gallon		Amount (in millions)		Per Gallon
Volume		40.5				44.7
Sales	$	108.1	$	2.6665	$	109.1	$	2.4403
Cost	$	61.7	$	1.5210	$	64.1	$	1.4330
Gross Profit	$	46.4	$	1.1455	$	45.1	$	1.0073
Other Petroleum Products	Amount (in millions)		Per Gallon		Amount (in millions)		Per Gallon
Volume		27.5				27.2
Sales	$	50.4	$	1.8325	$	47.1	$	1.7288
Cost	$	42.6	$	1.5483	$	39.5	$	1.4494
Gross Profit	$	7.8	$	0.2842	$	7.6	$	0.2794
Total Product	Amount (in millions)				Amount (in millions)
Sales	$	158.5			$	156.2
Cost	$	104.3			$	103.6
Gross Profit	$	54.3			$	52.7

For the three months ended June 30, 2017, total product gross profit was $54.3 million, which was $1.6 million, or 3.0%, higher than the three months ended June 30 2016 as an increase in home heating oil and propane margins ($5.6 million) and higher gross profit from other petroleum products ($0.2 million) was reduced by a decline in home heating oil and propane volume ($4.2 million).

Cost of Installations and Service

Installation costs for the three months ended June 30, 2017 were $20.2 million, $2.5 million higher than the three months ended June 30, 2016 largely due to higher air conditioning installations. Installation costs as a percentage of installation sales for the three months ended June 30, 2017 and the three months ended June 30, 2016 were 82.0% and 83.2%, respectively.

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Service expenses increased $2.4 million, or 6.8%, to $38.0 million for the three months ended June 30, 2017, or 89.2% of service sales, versus $35.5 million, or 87.4% of service sales, for the three months ended June 30, 2016. The increase of $2.4 million was due to the expense needed to support the rise in air conditioning service revenue, higher cost attributable to the growth in other services, expansion of our propane business, training costs for our new service platform as well as normal expense increases. We experienced a combined gross profit from service and installation of $9.0 million for the three months ended June 30, 2017 compared to $8.7 million for the three months ended June 30, 2016. Management views the service and installation department on a combined basis because many overhead functions cannot be separated or precisely allocated to either service or installation billings.

(Increase) Decrease in the Fair Value of Derivative Instruments

During the three months ended June 30, 2017, the change in the fair value of derivative instruments resulted in a $3.1 million charge due to a decrease in the market value for unexpired hedges (a $3.8 million charge) and a $0.7 million credit due to the expiration of certain hedged positions.

During the three months ended June 30, 2016, the change in the fair value of derivative instruments resulted in an $11.3 million credit due to an increase in the market value for unexpired hedges (an $11.2 million credit) and a $0.1 million credit due to the expiration of certain hedged positions.

Delivery and Branch Expenses

For the three months ended June 30, 2017, delivery and branch expenses increased $3.6 million, or 5.6%, to $67.6 million, compared to $64.1 million for the three months ended June 30, 2016, due to an acquisition-related increase of $0.8 million and higher delivery and branch expenses in the base business of $2.7 million, or 4.2%. The increase in the base business was largely due to additional staffing in the areas of information technology, customer service, operations management, sales and marketing and the costs related to implementing new technology which aggregated $2.2 million. We believe that this expense increase contributed to and positively impacted our net customer attrition.

Depreciation and Amortization

For the three months ended June 30, 2017, depreciation and amortization expense increased by $1.0 million, or 14.7%, to $7.4 million, compared to $6.5 million for the three months ended June 30, 2016 as a result of accelerated amortization of certain tradenames related to rebranding.

General and Administrative Expenses

For the three months ended June 30, 2017, general and administrative expenses increased $0.2 million, to $6.2 million, from $6.0 million for the three months ended June 30, 2016 due to higher legal expenses.

Finance Charge Income

For the three months ended June 30, 2017, finance charge income increased by $0.4 million, or 38.4%, to $1.3 million compared to $0.9 million for the three months ended June 30, 2016. The increase in the wholesale cost of product and in volume during the heating season led to higher product sales and thus an increase in accounts receivable balances subject to a finance charge.

Interest Expense, Net

For the three months ended June 30, 2017, interest expense decreased $0.1 million, or 6.5%, to $1.6 million compared to $1.7 million for the three months ended June 30, 2016 as an increase in income earned in cash balances and a reduction in debt of $16.2 million was largely offset by an increase in long-term borrowing rates.

Amortization of Debt Issuance Costs

For the three months ended June 30, 2017, amortization of debt issuance costs was $0.3 million, unchanged from the three months ended June 30, 2016.

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Income Tax Benefit

For the three months ended June 30, 2017, income tax benefit increased by $6.7 million to $8.4 million, from $1.8 million for the three months ended June 30, 2016, primarily due to a decrease in income before income taxes of $16.8 million. The Partnership’s effective income tax rate was 38.7% for the three months ended June 30, 2017, compared to 35.1% for the three months ended June 30, 2016.

Net Loss

For the three months ended June 30, 2017, the Partnership’s net loss increased $10.1 million, or 311.7%, to $13.3 million, from $3.2 million for the three months ended June 30, 2016, largely due to the after-tax impact of the non-cash change in the fair value of derivative instruments.

Adjusted EBITDA Loss

For the three months ended June 30, 2017, the Adjusted EBITDA loss increased by $1.5 million, or 19.2%, to $9.3 million as the decline in home heating oil and propane volume and an increase in certain operating expenses was partially offset by the additional gross profit provided by higher home heating oil and propane margins and an improvement in service and installation profitability.

EBITDA and Adjusted EBITDA should not be considered as an alternative to net income (as an indicator of operating performance) or as an alternative to cash flow (as a measure of liquidity or ability to service debt obligations), but each provides additional information for evaluating our ability to make the Minimum Quarterly Distribution.

EBITDA and Adjusted EBITDA are calculated as follows:

	Three Months Ended June 30,
(in thousands)	2017			2016
Net loss	$	(13,332	)	$	(3,238	)
Plus:
Income tax benefit		(8,434	)		(1,755	)
Amortization of debt issuance cost		336			307
Interest expense, net		1,619			1,731
Depreciation and amortization		7,418			6,468
EBITDA		(12,393	)		3,513
(Increase) / decrease in the fair value of derivative instruments		3,135			(11,283	)
Adjusted EBITDA		(9,258	)		(7,770	)
Add / (subtract)
Income tax benefit		8,434			1,755
Interest expense, net		(1,619	)		(1,731	)
Provision for losses on accounts receivable		736			308
Decrease in accounts receivables		71,107			38,425
Decrease in inventories		3,119			3,159
Increase in customer credit balances		8,116			13,191
Change in deferred taxes		(2,670	)		5,004
Decrease in weather hedge contract receivable		—			12,500
Change in other operating assets and liabilities		(18,879	)		(28,891	)
Net cash provided by operating activities	$	59,086		$	35,950
Net cash used in investing activities	$	(8,376	)	$	(2,913	)
Net cash used in financing activities	$	(8,967	)	$	(8,495	)

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a) EBITDA (Earnings from continuing operations before net interest expense, income taxes, depreciation and amortization) and Adjusted EBITDA (Earnings from continuing operations before net interest expense, income taxes, depreciation and amortization, (increase) decrease in the fair value of derivatives, multiemployer pension plan withdrawal charge, gain or loss on debt redemption, goodwill impairment, and other non-cash and non-operating charges) 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:

• our compliance with certain financial covenants included in our debt agreements;

• our financial performance without regard to financing methods, capital structure, income taxes, or historical cost basis;

• our operating performance and return on invested capital compared to those of other companies in the retail distribution of refined petroleum products, without regard to financing methods and capital structure;

• our ability to generate cash sufficient to pay interest on our indebtedness and to make distributions to our partners; and

• the viability of acquisitions and capital expenditure projects and the overall rates of return of alternative investment opportunities.

The method of calculating Adjusted EBITDA may not be consistent with that of other companies, and EBITDA and Adjusted EBITDA both have limitations as analytical tools and, as such, should not be viewed in isolation but in conjunction with measurements that are computed in accordance with GAAP. Some of the limitations of EBITDA and Adjusted EBITDA are:

• EBITDA and Adjusted EBITDA do not reflect our cash used for capital expenditures

• Although depreciation and amortization are non-cash charges, the assets being depreciated or amortized often will have to be replaced and EBITDA and Adjusted EBITDA do not reflect the cash requirements for such replacements;

• EBITDA and Adjusted EBITDA do not reflect changes in, or cash requirements for, our working capital requirements;

• EBITDA and Adjusted EBITDA do not reflect the cash necessary to make payments of interest or principal on our indebtedness; and

• EBITDA and Adjusted EBITDA do not reflect the cash required to pay taxes.

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Nine Months Ended June 30, 2017

Compared to the Nine Months Ended June 30, 2016

Volume

For the nine months ended June 30, 2017, retail volume of home heating oil and propane sold increased by 12.4 million gallons, or 4.4%, to 294.3 million gallons, compared to 281.9 million gallons for the nine months ended June 30, 2016. For those locations where the Partnership had existing operations during both periods, which we sometimes refer to as the “base business” (i.e., excluding acquisitions), temperatures (measured on a heating degree day basis) for the nine months ended June 30, 2017 were 7.0% colder than the nine months ended June 30, 2016 and 12.4% warmer than normal, as reported by NOAA. For the twelve months ended June 30, 2017, net customer attrition for the base business was 2.8%. The impact of fuel conservation, along with any period-to-period differences in delivery scheduling, the timing of accounts added or lost during the fiscal years, equipment efficiency, and other volume variances not otherwise described, are included in the chart below under the heading “Other.” An analysis of the change in the retail volume of home heating oil and propane, which is based on management’s estimates, sampling, and other mathematical calculations and certain assumptions, is found below:

(in millions of gallons)	Heating Oil and Propane
Volume - Nine months ended June 30, 2016		281.9
Acquisitions		2.7
Impact of colder temperatures		18.6
Net customer attrition		(10.0	)
Other		1.1
Change		12.4
Volume - Nine months ended June 30, 2017		294.3

The following chart sets forth the percentage by volume of total home heating oil sold to residential variable-price customers, residential price-protected customers, and commercial/industrial/other customers for the nine months ended June 30, 2017 compared to the nine months ended June 30, 2016:

	Nine Months Ended
Customers	June 30, 2017			June 30, 2016
Residential Variable		42.6	%		40.8	%
Residential Price-Protected		45.1	%		46.6	%
Commercial/Industrial/Other		12.3	%		12.6	%
Total		100.0	%		100.0	%

Volume of other petroleum products sold increased by 1.8 million gallons, or 2.3%, to 83.4 million gallons for the nine months ended June 30, 2017, compared to 81.6 million gallons for the nine months ended June 30, 2016, due to an increase in the base business of 0.6 million gallons, or 0.7%, and acquisitions which contributed an additional 1.2 million gallons.

Product Sales

For the nine months ended June 30, 2017, product sales increased $136.8 million, or 16.8%, to $950.3 million, compared to $813.5 million for the nine months ended June 30, 2016, reflecting an increase in wholesale product costs of $0.2668 per gallon, or 20.5%, and an increase in total volume of 3.9%.

Installations and Service

For the nine months ended June 30, 2017, installation and service sales increased $5.9 million, or 3.2%, to $191.7 million, compared to $185.8 million for the nine months ended June 30, 2016, largely due to higher air conditioning installation and service, sales growth in other services and acquisitions.

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Cost of Product

For the nine months ended June 30, 2017, cost of product increased $119.3 million, or 25.2%, to $592.8 million, compared to $473.5 million for the nine months ended June 30, 2016, due largely to a $0.2668 per gallon, or 20.5%, increase in wholesale product cost and an increase in total volume of 3.9%.

Gross Profit—Product

The table below calculates the Partnership’s per gallon margins and reconciles product gross profit for home heating oil and propane and other petroleum products. We believe the change in home heating oil and propane 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 and propane margins for the nine months ended June 30, 2017 increased by $0.0141 per gallon, or 1.3%, to $1.1360 per gallon, from $1.1219 per gallon during the nine months ended June 30, 2016. Product sales and cost of product include home heating oil, propane, other petroleum products and liquidated damages billings.

	Nine Months Ended
	June 30, 2017				June 30, 2016
Home Heating Oil and Propane	Amount (in millions)		Per Gallon		Amount (in millions)		Per Gallon
Volume		294.3				281.9
Sales	$	795.5	$	2.7034	$	681.3	$	2.4166
Cost	$	461.3	$	1.5674	$	365.0	$	1.2946
Gross Profit	$	334.2	$	1.1360	$	316.3	$	1.1219
Other Petroleum Products	Amount (in millions)		Per Gallon		Amount (in millions)		Per Gallon
Volume		83.4				81.6
Sales	$	154.8	$	1.8548	$	132.2	$	1.6205
Cost	$	131.5	$	1.5766	$	108.6	$	1.3296
Gross Profit	$	23.3	$	0.2782	$	23.7	$	0.2909
Total Product	Amount (in millions)				Amount (in millions)
Sales	$	950.3			$	813.5
Cost	$	592.8			$	473.5
Gross Profit	$	357.5			$	340.0

For the nine months ended June 30, 2017, total product gross profit was $357.5 million, which was $17.5 million, or 5.2%, more than the nine months ended June 30, 2016, due to an increase in home heating oil and propane volume ($13.8 million) sold at slightly higher margins ($4.1 million), partly offset by a $0.4 million lower gross profit from other petroleum products.

Cost of Installations and Service

Total installation costs for the nine months ended June 30, 2017 increased by $2.4 million, or 4.2%, to $58.8 million, compared to $56.4 million in installation costs for the nine months ended June 30, 2016, largely due to higher air conditioning installations. Installation costs as a percentage of installation sales for the nine months ended June 30, 2017 and the nine months ended June 30, 2016, were 82.9% and 83.7%, respectively.

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Service expense increased $5.7 million, or 4.8% to $124.3 million for the nine months ended June 30, 2017, or 103.0% of service sales, versus $118.7 million, or 100.3% of service sales, for the nine months ended June 30, 2016. Service expenses were higher due to the increased need to service our customer base during the first quarter of fiscal 2017 in response to 33.6% colder temperatures versus the first quarter of fiscal 2016 (which was unusually warm). Service expenses also increased due to the cost required to support the rise in air conditioning service revenue, expense attributable to the growth in other services, expansion of our propane business, training costs for our new service platform as well as normal expense increases. We realized a combined gross profit from service and installation of $8.5 million for the nine months ended June 30, 2017 compared to a combined gross profit of $10.7 million for the nine months ended June 30, 2016. The Partnership is currently evaluating its pricing and staffing models for its service offerings in several markets to increase the overall service profitability. Management views the service and installation department on a combined basis because many overhead functions cannot be separated or precisely allocated to either service or installation billings.

(Increase) Decrease in the Fair Value of Derivative Instruments

During the nine months ended June 30, 2017, the change in the fair value of derivative instruments resulted in a $7.0 million charge as a decrease in the market value for unexpired hedges (a $1.5 million charge) added to a $5.5 million charge due to the expiration of certain hedged positions.

During the nine months ended June 30, 2016, the change in the fair value of derivative instruments resulted in a $20.1 million credit due to an increase in the market value for unexpired hedges (a $6.5 million credit) and a $13.6 million credit due to the expiration of certain hedged positions.

Delivery and Branch Expenses

For the nine months ended June 30, 2017, delivery and branch expenses increased $22.2 million, or 10.2%, to $241.0 million, compared to $218.8 million for the nine months ended June 30, 2016, due to the absence of a $12.5 million credit as was recorded in the first quarter of 2016 under the Partnership’s weather hedge contract, higher delivery expense of $2.5 million, or 1.3%, due in part to the weather-related increase in home heating oil and propane volume of 4.4%, $1.9 million due to acquisition related increases, and an increase in spending of $5.3 million largely due to additional staffing in the areas of information technology, customer service, operations management, sales and marketing, and the costs related to implementing new technology. We believe that the $5.3 million expense increase contributed to and positively impacted the 11,000 account improvement in net customer attrition.

Depreciation and Amortization

For the nine months ended June 30, 2017, depreciation and amortization expense increased by $0.7 million, or 3.7%, to $20.7 million, compared to $20.0 million for the nine months ended June 30, 2016 as a result of accelerated amortization of certain tradenames related to rebranding.

General and Administrative Expenses

For the nine months ended June 30, 2017, general and administrative expenses increased $0.6 million, to $18.1 million, from $17.5 million for the nine months ended June 30, 2016, primarily due to higher legal and professional expense.

Finance Charge Income

For the nine months ended June 30, 2017, finance charge income increased by $0.8 million, or 32.6%, to $3.3 million compared to $2.5 million for the nine months ended June 30, 2016. The increase in the wholesale cost of product and the increase in volume led to higher product sales and thus an increase in accounts receivable balances subject to a finance charge.

Interest Expense, Net

For the nine months ended June 30, 2017, interest expense decreased $0.4 million, or 6.6%, to $5.1 million compared to $5.5 million for the nine months ended June 30, 2016 as a reduction in debt of $16.2 million and an increase in income earned on cash balances was somewhat offset by an increase in long-term borrowing rates.

Amortization of Debt Issuance Costs

For the nine months ended June 30, 2017, amortization of debt issuance costs was $1.0 million unchanged from the nine months ended June 30, 2016.

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Income Tax Expense

For the nine months ended June 30, 2017, the Partnership’s income tax expense decreased by $14.8 million to $31.7 million, from $46.6 million for the nine months ended June 30, 2016, primarily due to a decrease in income before income taxes of $34.2 million. The Partnership’s effective income tax rate was 41.5% for the nine months ended June 30, 2017, compared to 42.1% for the nine months ended June 30, 2016.

Net Income

For the nine months ended June 30, 2017, net income decreased $19.4 million, or 30.3%, to $44.6 million, from $64.0 million for the nine months ended June 30, 2016 largely due to the after tax impact of the non cash change in the fair value of derivative instruments.

Adjusted EBITDA

For the nine months ended June 30, 2017, Adjusted EBITDA decreased by $6.7 million, or 5.7%, to $110.2 million as the impact of higher home heating oil and propane volume and slightly higher home heating oil and propane margins were more than offset by the absence of a $12.5 million credit that was recorded in the first quarter of 2016 under the Partnership’s weather hedge contract, lower services and installations gross profit and additional staffing in the areas of information technology, customer service, operations management and sales and marketing.

EBITDA and Adjusted EBITDA should not be considered as an alternative to net income (as an indicator of operating performance) or as an alternative to cash flow (as a measure of liquidity or ability to service debt obligations), but each provides additional information for evaluating our ability to make the Minimum Quarterly Distribution.

EBITDA and Adjusted EBITDA are calculated as follows:

	Nine Months Ended June 30,
(in thousands)	2017			2016
Net income	$	44,647		$	64,029
Plus:
Income tax expense		31,721			46,566
Amortization of debt issuance cost		972			934
Interest expense, net		5,118			5,481
Depreciation and amortization		20,705			19,959
EBITDA		103,163			136,969
(Increase) / decrease in the fair value of derivative instruments		7,026			(20,071	)
Adjusted EBITDA		110,189			116,898
Add / (subtract)
Income tax expense		(31,721	)		(46,566	)
Interest expense, net		(5,118	)		(5,481	)
Provision (recovery) for losses on accounts receivable		2,261			(140	)
(Increase) decrease in accounts receivables		(40,524	)		647
Decrease in inventories		3,761			13,402
Decrease in customer credit balances		(45,757	)		(2,026	)
Change in deferred taxes		4,451			13,299
Change in other operating assets and liabilities		25,668			20,152
Net cash provided by operating activities	$	23,210		$	110,185
Net cash used in investing activities	$	(35,219	)	$	(15,756	)
Net cash used in financing activities	$	(32,355	)	$	(23,781	)

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• EBITDA (Earnings from continuing operations before net interest expense, income taxes, depreciation and amortization) and Adjusted EBITDA (Earnings from continuing operations before net interest expense, income taxes, depreciation and amortization, (increase) decrease in the fair value of derivatives, multiemployer pension plan withdrawal charge, gain or loss on debt redemption, goodwill impairment, and other non-cash and non-operating charges) 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:

• our compliance with certain financial covenants included in our debt agreements;

• our financial performance without regard to financing methods, capital structure, income taxes or historical cost basis;

• our operating performance and return on invested capital compared to those of other companies in the retail distribution of refined petroleum products, without regard to financing methods and capital structure;

• our ability to generate cash sufficient to pay interest on our indebtedness and to make distributions to our partners; and

• the viability of acquisitions and capital expenditure projects and the overall rates of return of alternative investment opportunities.

The method of calculating Adjusted EBITDA may not be consistent with that of other companies, and EBITDA and Adjusted EBITDA both have limitations as analytical tools and so should not be viewed in isolation but in conjunction with measurements that are computed in accordance with GAAP. Some of the limitations of EBITDA and Adjusted EBITDA are:

• EBITDA and Adjusted EBITDA do not reflect our cash used for capital expenditures.

• Although depreciation and amortization are non-cash charges, the assets being depreciated or amortized often will have to be replaced and EBITDA and Adjusted EBITDA do not reflect the cash requirements for such replacements;

• EBITDA and Adjusted EBITDA do not reflect changes in, or cash requirements for, our working capital requirements;

• EBITDA and Adjusted EBITDA do not reflect the cash necessary to make payments of interest or principal on our indebtedness; and

• EBITDA and Adjusted EBITDA do not reflect the cash required to pay taxes.

DISCUSSION OF CASH FLOWS

We use the indirect method to prepare our Consolidated Statements of Cash Flows. Under this method, we reconcile net income to cash flows provided by operating activities by adjusting net income for those items that impact net income but do not result in actual cash receipts or payment during the period.

Operating Activities

Due to the seasonal nature of our business, cash is generally used in operations during the winter (our first and second fiscal quarters) as we require additional working capital to support the high volume of sales during this period, and cash is generally provided by operating activities during the spring and summer (our third and fourth quarters) when customer payments exceed the cost of deliveries.

During the nine months ended June 30, 2017, cash provided by operating activities decreased by $87.0 million to $23.2 million, when compared to $110.2 million of cash provided by operating activities during the nine months ended June 30, 2016, as an unfavorable change in cash relating to accounts receivable of $84.9 million (including customer credit balances), and an increase in the cash used to purchase inventory of $9.6 million was reduced by an increase of $2.1 million in cash generated from operations and the timing of cash used to fund accounts payable, income taxes, and other cash payments of $5.4 million. The impact of colder weather and an increase in per gallon product cost drove increases in accounts receivable and product purchases and resulted in a much greater but expected use of cash.

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Investing Activities

Our capital expenditures for the nine months ended June 30, 2017 totaled $9.3 million, as we invested in computer hardware and software ($3.0 million), refurbished certain physical plants ($2.0 million), expanded our propane operations ($2.0 million) and made additions to our fleet and other equipment ($2.3 million). We also completed five acquisitions for $16.0 million; $14.5 million in cash and $1.5 million of deferred liabilities (including $0.6 million of contingent consideration). The gross purchase price was allocated $9.3 million to intangible assets, $2.5 million to goodwill and $5.0 million to fixed assets and received credit for a negative working capital position of $0.8 million.

Our capital expenditures for the nine months ended June 30, 2016 totaled $7.2 million, as we invested in computer hardware and software ($2.0 million), refurbished certain physical plants ($0.9 million), expanded our propane operations ($2.3 million) and made additions to our fleet and other equipment ($2.0 million). We also completed three acquisitions for $8.8 million and allocated $5.2 million of the gross purchase price to intangible assets, $1.6 million to goodwill, $2.2 million to fixed assets and received credit for a negative working capital position of $0.2 million.

Financing Activities

During the nine months ended June 30, 2017, we paid distributions of $17.6 million to our Common Unit holders and $0.4 million to our General Partner unit holders (including $0.3 million of incentive distributions as provided in our Partnership Agreement) and repaid $13.7 million of our term loan.

During the nine months ended June 30, 2016, we paid distributions of $16.7 million to our Common Unit holders and $0.4 million to our General Partner unit holders (including $0.3 million of incentive distributions as provided in our Partnership Agreement) and repaid $5.0 million of our term loan. We also repurchased 0.95 million units for $0.7 million in connection with our unit repurchase plan.

FINANCING AND SOURCES OF LIQUIDITY

Liquidity and Capital Resources Comparatives

Our primary uses of liquidity are to provide funds for our working capital, capital expenditures, distributions on our units, acquisitions, and unit repurchases. Our ability to provide funds for such uses depends on our future performance, which will be subject to prevailing economic, financial, business and weather conditions, the ability to pass on the full impact of high product costs to customers, the effects of high net customer attrition, conservation, and other factors. Capital requirements, at least in the near term, are expected to be provided by cash flows from operating activities, cash on hand as of June 30, 2017 ($94.6 million) or a combination thereof. To the extent future capital requirements exceed cash on hand plus cash flows from operating activities, we anticipate that working capital will be financed by our revolving credit facility, as discussed below, and repaid from subsequent seasonal reductions in inventory and accounts receivable. As of June 30, 2017, we had no borrowings under our revolving credit facility and $48.2 million in letters of credit were outstanding, primarily for current and future insurance reserves. Our ability to borrow was reduced by $4.9 million to secure hedges with the bank group.

Under the terms of the third amended and restated credit agreement, we must maintain at all times Availability (borrowing base less amounts borrowed and letters of credit issued) of 12.5% of the maximum facility size and a fixed charge coverage ratio of not less than 1.1. We must also maintain a senior secured leverage ratio that at any time cannot be more than 3.0 as calculated during the quarters ending June or September, and at any time no more than 4.5 as calculated during the quarters ending December or March. As of June 30, 2017, Availability, as defined in the credit agreement, was $160.3 million and we were in compliance with the fixed charge coverage ratio and senior secured leverage ratio.

Maintenance capital expenditures for the remainder of fiscal 2017 are estimated to be approximately $1.2 million, excluding the capital requirements for leased fleet. In addition, we plan to invest an additional $0.5 million in our propane operations and make a $1.0 million pension contribution. Distributions for the balance of fiscal 2017, at the current quarterly level of $0.11 per unit, would result in an aggregate of approximately $6.1 million to Common Unit holders, $0.2 million to our General Partner (including $0.1 million of incentive distribution as provided for in our Partnership Agreement), and $0.1 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. Under the terms of our credit facility, our term loan is repayable in quarterly payments of $2.5 million, and depending on our fiscal 2017 results, we may be required to make an additional payment. (see Note 9-Long-Term Debt and Bank Facility Borrowings). In addition, we intend to continue to repurchase Common Units pursuant to our unit repurchase plan and seek attractive acquisition opportunities within the Availability constraints of our revolving credit facility and funding resources.

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Contractual Obligations and Off-Balance Sheet Arrangements

There has been no material change to Contractual Obligations and Off-Balance Sheet Arrangements since our September 30, 2016 Form 10-K disclosure and therefore, the table has not been included in this Form 10-Q.

Recent Accounting Pronouncements

The following new accounting standards were recently adopted by the Partnership, and are more fully described in Note 2 - Summary of Significant Accounting Policies – Recently Adopted Accounting Pronouncements, of the consolidated financial statements:

• ASU No. 2015-03, Interest - Imputation of Interest, Simplifying the Presentation of Debt Issuance Costs

• ASU No. 2015-16, Simplifying the Accounting for Measurement-Period Adjustments

• ASU No. 2016-18, Statement of Cash Flow (Topic 230): Restricted cash

The following new accounting standards are currently being evaluated by the Partnership, and are more fully described in Note 2 - Summary of Significant Accounting Policies – Recently Issued Accounting Pronouncements, of the consolidated financial statements:

• ASU No. 2014-09, Revenue from Contracts with Customers

• ASU No. 2015-11, Simplifying the Measurement of Inventory

• ASU No. 2016-02, Leases

• ASU No. 2016-13, Financial Instruments – Credit Losses

• ASU No. 2016-15, Statement of Cash Flow

• ASU No. 2017-01, Business Combinations, Clarifying the definition of a business

• ASU No. 2017-04, Intangibles – Goodwill and Other, Simplifying the test for goodwill impairment

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

We are exposed to interest rate risk primarily through our bank credit facilities. We utilize these borrowings to meet our working capital needs.

At June 30, 2017, we had outstanding borrowings totaling $78.8 million, which are subject to variable interest rates under our credit agreement. In the event that interest rates associated with this facility were to increase 100 basis points, the after tax impact on annual future cash flows would be a decrease of $0.5 million.

We regularly use derivative financial instruments to manage our exposure to market risk related to changes in the current and future market price of home heating oil and vehicle fuels. The value of market sensitive derivative instruments is subject to change as a result of movements in market prices. Sensitivity analysis is a technique used to evaluate the impact of hypothetical market value changes. Based on a hypothetical ten percent increase in the cost of product at June 30, 2017, the potential impact on our hedging activity would be to increase the fair market value of these outstanding derivatives by $4.0 million to a negative fair market value of $1.2 million; and conversely a hypothetical ten percent decrease in the cost of product would decrease the fair market value of these outstanding derivatives by $3.4 million to a negative fair market value of $8.7 million.

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Item 4.

Controls and Procedures

a) Evaluation of disclosure controls and procedures

The General Partner’s chief executive officer and its chief financial officer evaluated the effectiveness of the Partnership’s disclosure controls and procedures (as that term is defined in Rule 13a-15(e) of the Securities Exchange Act of 1934, as amended) as of June 30, 2017. Based on that evaluation, such chief executive officer and chief financial officer concluded that the Partnership’s disclosure controls and procedures were effective as of June 30, 2017, at the reasonable level of assurance. For purposes of Rule 13a-15(e), the term disclosure controls and procedures means controls and other procedures of an issuer that are designed to ensure that information required to be disclosed by the issuer in the reports that it files or submits under the Act (15 U.S.C. 78a et seq.) is recorded, processed, summarized and reported, within the time periods specified in the Commission’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Act is accumulated and communicated to the issuer’s management, including its chief executive and chief financial officer, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.

b) Change in Internal Control over Financial Reporting

No change in the Partnership’s internal control over financial reporting occurred during the Partnership’s most recent fiscal quarter that has materially affected or is reasonably likely to materially affect the Partnership’s internal control over financial reporting.

c) Other

The General Partner and the Partnership believe that a controls system, no matter how well designed and operated, cannot provide absolute assurance that the objectives of the controls system are met, and no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within a Partnership have been detected. Therefore, a control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Our disclosure controls and procedures are designed to provide such reasonable assurances of achieving our desired control objectives, and the chief executive officer and chief financial officer of our General Partner have concluded, as of June  30, 2017, that our disclosure controls and procedures were effective in achieving that level of reasonable assurance.

PART II OTHER INFORMATION

Item 1.

Legal Proceedings

On February 18, 2016, a civil action was filed in the United States District Court, District of New Jersey, entitled M. Norman Donnenfeld v. Petro Home Services, Petro Holdings Inc. and Petro, Inc., Civil Action Number 2:16-cv-00882 JMV-JBC, against Petro Home Services which is a brand name, Petro Holdings Inc. and Petro, Inc. Plaintiff alleged he did not receive expected contractual benefits under his protected price plan contract when oil prices fell and asserted various claims for relief including breach of contract, violation of the New York General Business Law and fraud. The Plaintiff also sought to have a class certified of all customers of the defendants in the United States who entered into protected price plan contracts and were denied the same contractual benefits and to be appointed to represent them. The Plaintiff sought compensatory, punitive and other damages in unspecified amounts. On May 9, 2016, the Partnership filed a motion to dismiss the complaint for lack of personal jurisdiction and failure to state a claim for relief and to strike the class action allegations. On March 24, 2017, the motion to dismiss the complaint was granted, for failure to state a claim and for lack of personal jurisdiction but Plaintiff was given 30 days to attempt to replead.

Instead of filing an amended complaint, on April 18, 2017, Plaintiff commenced a new putative class action in the United States District Court for the Eastern District of New York, entitled M. Norman Donnenfeld v. Petro, Inc., Civil Action Number 2:17-cv-02310-JFB-SIL. The new complaint names Petro, Inc. d/b/a Petro Home Services as the sole defendant. The allegations and claims in the new complaint are substantially similar to those in the prior complaint filed in the District of New Jersey. No class has yet been certified in this action. The Partnership believes the allegations lack merit and intends to vigorously defend the action; at this time we cannot assess the potential outcome or materiality of this matter.

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Item 1A.

Risk Factors

In addition to the other information set forth in this Report, investors should carefully review and consider the information regarding certain factors which could materially affect our business, results of operations, financial condition and cash flows set forth in Part I Item 1A. “Risk Factors” in our Fiscal 2016 Form 10-K. We may disclose changes to such factors or disclose additional factors from time to time in our future filings with the SEC.

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

Not applicable.

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Item 6.

Exhibits

(a) Exhibits Included Within:

31.1	Certification of Chief Executive Officer, Star Gas Partners, L.P., pursuant to Rule 13a-14(a)/15d-14(a).
31.2	Certification of Chief Financial Officer, Star Gas Partners, L.P., pursuant to Rule 13a-14(a)/15d-14(a).
32.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101	The following materials from the Star Gas Partners, L.P. Quarterly Report on Form 10-Q for the quarter ended June 30, 2017, formatted in Extensible Business Reporting Language (XBRL): (i) the Condensed Consolidated Balance Sheets, (ii) the Condensed Consolidated Statements of Operations, (iii) the Condensed Consolidated Statements of Comprehensive Income, (iv) the Condensed Consolidated Statements of Partners’ Capital, (v) the Condensed Consolidated Statements of Cash Flows and (vi) related notes.
101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Extension Schema Document.
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.
101.LAB	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on its behalf of the undersigned thereunto duly authorized:

Star Gas Partners, L.P.
(Registrant)
By:	Kestrel Heat LLC AS GENERAL PARTNER

Signature	Title	Date
/s/ Richard F. Ambury Richard F. Ambury	Executive Vice President, Chief Financial Officer, Treasurer and Secretary Kestrel Heat LLC (Principal Financial Officer)	July 31, 2017
Signature	Title	Date
/s/ Cory A. Czekanski Cory A. Czekanski	Vice President – Controller Kestrel Heat LLC (Principal Accounting Officer)	July 31, 2017

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EX-31.1

Exhibit 31.1

CERTIFICATIONS

I, Steven J. Goldman, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Star Gas Partners, L.P. (“Registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) designed such internal controls over financial reporting, or caused such internal controls over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information and;

(b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: July 31, 2017

/s/ Steven J. Goldman

Steven J. Goldman

President and Chief Executive Officer

Star Gas Partners, L.P.

EX-31.2

Exhibit 31.2

CERTIFICATIONS

I, Richard F. Ambury, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Star Gas Partners, L.P. (“Registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrants’ other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal controls over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) designed such internal controls over financial reporting, or caused such internal controls over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(c) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information and;

(d) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: July 31, 2017

/s/ Richard F. Ambury

Richard F. Ambury

Chief Financial Officer

Star Gas Partners, L.P.

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906

OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Star Gas Partners, L.P. (the “Partnership”) on Form 10-Q for the quarterly period ended June 30, 2017, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Steven J. Goldman, President and Chief Executive Officer of the Partnership, certify to my knowledge pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, following due inquiry, I believe that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Partnership.

A signed original of this written statement required by Section 906 has been provided to Star Gas Partners, L.P. and will be retained by Star Gas Partners, L.P. and furnished to the Securities and Exchange Commission or its staff upon request.

	STAR GAS PARTNERS, L.P.
	By:	KESTREL HEAT, LLC (General Partner)
Date: July 31, 2017	By:	/s/ Steven J. Goldman
		Steven J. Goldman
		President and Chief Executive Officer
		Star Gas Partners, L.P.

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Star Gas Partners, L.P. (the “Partnership”) on Form 10-Q for the quarterly period ended June 30, 2017, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Richard F. Ambury, Chief Financial Officer of the Partnership, certify to my knowledge pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, following due inquiry, I believe that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Partnership.

A signed original of this written statement required by Section 906 has been provided to Star Gas Partners, L.P. and will be retained by Star Gas Partners, L.P. and furnished to the Securities and Exchange Commission or its staff upon request.

	STAR GAS PARTNERS, L.P.
	By:	KESTREL HEAT, LLC (General Partner)
Date: July 31, 2017	By:	/s/ Richard F. Ambury
		Richard F. Ambury
		Chief Financial Officer
		Star Gas Partners, L.P.

XML

Document and Entity Information - shares	9 Months Ended
	Jun. 30, 2017	Jul. 31, 2017
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q3
Trading Symbol	SGU
Entity Registrant Name	STAR GAS PARTNERS LP
Entity Central Index Key	0001002590
Current Fiscal Year End Date	--09-30
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		55,887,832

XML

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands		Jun. 30, 2017	Sep. 30, 2016
Current assets
Cash and cash equivalents		$ 94,574	$ 139,188
Receivables, net of allowance of $6,577 and $4,419, respectively		116,646	78,650
Inventories		42,422	45,894
Fair asset value of derivative instruments			3,987
Prepaid expenses and other current assets		24,409	27,139
Total current assets		278,051	294,858
Property and equipment, net		74,491	70,410
Goodwill		215,262	212,760
Intangibles, net		94,520	97,656
Deferred tax assets, net		255	5,353
Restricted cash		250
Investments	[1]	11,686
Deferred charges and other assets, net		9,782	11,074
Total assets		684,297	692,111
Current liabilities
Accounts payable		20,354	25,690
Fair liability value of derivative instruments		4,760	2,285
Current maturities of long-term debt		10,000	16,200
Accrued expenses and other current liabilities		130,776	103,855
Unearned service contract revenue		55,759	56,971
Customer credit balances		40,340	84,921
Total current liabilities		261,989	289,922
Long-term debt		68,155	75,441
Other long-term liabilities		25,082	25,255
Partners' capital
Common unitholders		349,554	322,771
General partner		(672)	(516)
Accumulated other comprehensive loss, net of taxes		(19,811)	(20,762)
Total partners' capital		329,071	301,493
Total liabilities and partners' capital		$ 684,297	$ 692,111

[1] See Note 2 - Investments

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CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2017	Sep. 30, 2016
Receivables, allowance	$ 6,577	$ 4,419

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands		3 Months Ended		9 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Sales:
Product		$ 158,531	$ 156,229	$ 950,307	$ 813,519
Installations and services		67,270	61,965	191,664	185,755
Total sales		225,801	218,194	1,141,971	999,274
Cost and expenses:
Cost of product		104,268	103,568	592,802	473,534
Cost of installations and services		58,224	53,272	183,137	175,042
(Increase) decrease in fair value of derivative instruments	[1]	3,135	(11,283)	7,026	(20,071)
Delivery and branch expenses		67,640	64,052	240,987	218,755
Depreciation and amortization expenses		7,418	6,468	20,705	19,959
General and administrative expenses		6,235	6,017	18,144	17,525
Finance charge income		(1,308)	(945)	(3,288)	(2,480)
Operating income (loss)		(19,811)	(2,955)	82,458	117,010
Interest expense, net		(1,619)	(1,731)	(5,118)	(5,481)
Amortization of debt issuance costs		(336)	(307)	(972)	(934)
Income (loss) before income taxes		(21,766)	(4,993)	76,368	110,595
Income tax expense (benefit)		(8,434)	(1,755)	31,721	46,566
Net income (loss)		(13,332)	(3,238)	44,647	64,029
General Partner's interest in net income (loss)		(79)	(19)	259	362
Limited Partners' interest in net income (loss)		$ (13,253)	$ (3,219)	$ 44,388	$ 63,667
Basic and diluted income (loss) per Limited Partner Unit	[2]	$ (0.24)	$ (0.06)	$ 0.70	$ 0.95
Weighted average number of Limited Partner units outstanding:
Basic and Diluted		55,888	57,188	55,888	57,237

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

[2] See Note 13 Earnings Per Limited Partner Unit.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Net income (loss)		$ (13,332)	$ (3,238)	$ 44,647	$ 64,029
Other comprehensive income:
Unrealized gain on pension plan obligation	[1]	532	647	1,598	1,943
Tax effect of unrealized gain on pension plan		(215)	(267)	(647)	(802)
Total other comprehensive income		317	380	951	1,141
Total comprehensive income (loss)		$ (13,015)	$ (2,858)	$ 45,598	$ 65,170

[1] This item is included in the computation of net periodic pension cost.

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CONDENSED CONSOLIDATED STATEMENT OF PARTNERS' CAPITAL - 9 months ended Jun. 30, 2017 - USD ($) shares in Thousands, $ in Thousands	Total		General Partner	Common Stock	Accumulated Other Comprehensive Income (Loss)
Beginning Balance at Sep. 30, 2016	$ 301,493		$ (516)	$ 322,771	$ (20,762)
Beginning Balance, unit at Sep. 30, 2016			326	55,888
Net income	44,647		$ 259	$ 44,388
Unrealized gain on pension plan obligation	1,598	[1]			1,598
Tax effect of unrealized gain on pension plan	(647)				(647)
Distributions	(18,020)		(415)	(17,605)
Ending Balance at Jun. 30, 2017	$ 329,071		$ (672)	$ 349,554	$ (19,811)
Ending Balance, Unit at Jun. 30, 2017			326	55,888

[1] This item is included in the computation of net periodic pension cost.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands		9 Months Ended
		Jun. 30, 2017	Jun. 30, 2016
Cash flows provided by (used in) operating activities:
Net income		$ 44,647	$ 64,029
Adjustment to reconcile net income to net cash provided by (used in) operating activities:
(Increase) decrease in fair value of derivative instruments	[1]	7,026	(20,071)
Depreciation and amortization		21,677	20,893
Provision (recovery) for losses on accounts receivable		2,261	(140)
Change in deferred taxes		4,451	13,299
Changes in operating assets and liabilities:
(Increase) decrease in receivables		(40,524)	647
Decrease in inventories		3,761	13,402
Decrease in other assets		3,443	968
Decrease in accounts payable		(3,468)	(2,173)
Decrease in customer credit balances		(45,757)	(2,026)
Increase in other current and long-term liabilities		25,693	21,357
Net cash provided by operating activities		23,210	110,185
Cash flows provided by (used in) investing activities:
Capital expenditures		(9,348)	(7,230)
Proceeds from sales of fixed assets		171	303
Purchase of investments	[2]	(11,538)
Acquisitions		(14,504)	(8,829)
Net cash used in investing activities		(35,219)	(15,756)
Cash flows used in financing activities:
Term loan repayment		(13,700)	(5,000)
Distributions		(18,020)	(17,097)
Unit repurchases			(707)
Customer retainage payments		(575)	(680)
Payments of debt issuance costs		(60)	(297)
Net cash used in financing activities		(32,355)	(23,781)
Net (decrease) increase in cash, cash equivalents, and restricted cash		(44,364)	70,648
Cash, cash equivalents, and restricted cash at beginning of period		139,188	100,508
Cash, cash equivalents, and restricted cash at end of period		$ 94,824	$ 171,156

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

[2] See Note 2 - Investments

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Partnership Organization

9 Months Ended

Jun. 30, 2017

Partnership Organization

1) Partnership Organization

Star Gas Partners, L.P. (“Star Gas Partners,” the “Partnership,” “we,” “us,” or “our”) is a full service provider specializing in the sale of home heating products and services to residential and commercial customers. The Partnership also services and sells heating and air conditioning equipment to its home heating oil and propane customers and to a lesser extent, provides these offerings to customers outside of our home heating oil and propane customer base. In certain of our marketing areas, we provide home security and plumbing services primarily to our home heating oil and propane customer base. We also sell diesel fuel, gasoline and home heating oil on a delivery only basis. These products and services are offered through our home heating oil and propane locations. The Partnership has one reportable segment for accounting purposes. We are the nation’s largest retail distributor of home heating oil based upon sales volume. Including our propane locations, we serve customers in the more northern and eastern states within the Northeast, Central and Southeast U.S. regions.

The Partnership is organized as follows:

• The Partnership is a master limited partnership, which as of June 30, 2017, had outstanding 55.9 million Common Units (NYSE: “SGU”), representing 99.4% limited partner interest in Star Gas Partners, and 0.3 million general partner units, representing 0.6% general partner interest in Star Gas Partners. The general partner of the Partnership 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”).

• The Partnership owns 100% of Star Acquisitions, Inc., a Minnesota corporation (“SA”) that owns 100% of Petro Holdings, Inc., a Minnesota corporation (“Petro”) and 100% of Woodbury Insurance Co., Inc., a Connecticut captive insurance corporation formed in July 2016 to insure large deductibles for certain insurance policies carried by Petro. SA and its subsidiaries are subject to Federal and state corporate income taxes. The Partnership’s operations are conducted through Petro and its subsidiaries. Petro is primarily a Northeast, Central and Southeast region retail distributor of home heating oil and propane that as of June 30, 2017, served approximately 441,000 full-service residential and commercial home heating oil and propane customers. Petro also sold diesel fuel, gasoline and home heating oil to approximately 73,000 customers on a delivery only basis. We installed, maintained, and repaired heating and air conditioning equipment and to a lesser extent provided these services outside our customer base including 14,900 service contracts for natural gas and other heating systems. In addition, we provided home security and plumbing to approximately 29,100 customers.

• Petroleum Heat and Power Co., Inc., a Minnesota corporation (“PH&P”) is a 100% owned subsidiary of the Partnership. PH&P is the borrower and the Partnership is the guarantor of the third amended and restated credit agreement’s $100 million five-year senior secured term loan and the $300 million ($450 million during the heating season of December through April of each year) revolving credit facility, both due July 30, 2020. (See Note 9—Long-Term Debt and Bank Facility Borrowings).

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Summary of Significant Accounting Policies

9 Months Ended

Jun. 30, 2017

Summary of Significant Accounting Policies

2) Summary of Significant Accounting Policies

Basis of Presentation

The Consolidated Financial Statements include the accounts of Star Gas Partners 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 and cash flows for the nine month period ended June 30, 2017, 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 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 and should be read in conjunction with the financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended September 30, 2016.

Comprehensive Income (Loss)

Comprehensive income (loss) is comprised of net income (loss) and other comprehensive income (loss). Other comprehensive income (loss) consists of the unrealized gain (loss) amortization on the Partnership’s pension plan obligation for its two frozen defined benefit pension plans and the corresponding tax effect.

Cash, cash equivalents, and restricted cash

At June 30, 2017, the $94.8 million of cash, cash equivalents, and restricted cash on the condensed consolidated statement of cash flows is composed of $94.6 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.

Investments

The investments are held by our captive insurance company in an irrevocable trust as collateral for workers’ compensation and automobile liability claims incurred and expected to be incurred in fiscal 2017. The collateral is required by a third party insurance carrier that insures per claim amounts above a set deductible. 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, the collateral is not expected to be used to pay obligations within the next twelve months.

Investments are currently comprised of $10.3 million of Level 1 debt securities and $1.4 million of mutual funds measured at net asset value.

Weather Hedge Contract

To partially mitigate the effect of weather on cash flows, the Partnership 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.

For fiscal years 2016 and 2017, the Partnership had weather hedge contracts that cover the five month period from November 1, through March 31, taken as a whole, for each respective fiscal year. The ultimate amount due to the Partnership (if any) was based on the entire five month accumulated calculation for the hedge period and had a maximum payout of $12.5 million for each respective fiscal year. In accordance with ASC 815-45-15, as of December 31, 2015, the Partnership recorded a credit of $12.5 million during fiscal 2016 under this contract that reduced delivery and branch expenses. No credit was recorded during the nine months ended June 30, 2017.

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

As of June 30, 2017, we had $0.2 million and $17.4 million balances 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. Based on the borrowing rates currently available to the Partnership for long-term financing of a similar maturity, the fair value of the NETTI Fund withdrawal liability as of June 30, 2017 was $22.2 million. 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

In April 2015, the FASB issued Accounting Standards Update (“ASU”) No. 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The update requires debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability instead of being presented as an asset. The Partnership retrospectively adopted the ASU effective December 31, 2016. As a result of the adoption, certain prior year balances (September 30, 2016) changed to conform to the current year presentation as follows: deferred charges and other assets, net decreased from $11.9 million to $11.1 million and long-term debt decreased from $76.3 million to $75.4 million.

In September 2015, the FASB issued ASU No. 2015-16, Simplifying the Accounting for Measurement-Period Adjustments, which requires an acquiring entity to recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The acquiring entity is required to record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. In addition, the acquiring entity is to present separately on the face of its income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods as if the adjustment to the provisional amounts had been recognized as of the acquisition date. The Partnership adopted the ASU effective December 31, 2016. The adoption of ASU No. 2015-16 did not have an impact on the Partnership’s consolidated financial statements and related disclosures.

In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flow (Topic 230): Restricted cash. The update requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The Partnership adopted the ASU effective December 31, 2016. The adoption of ASU No. 2016-18 did not have a material impact on the Partnership’s consolidated financial statements and related disclosures.

Recently Issued Accounting Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The FASB has also issued several updates to ASU 2014-09. This ASU will replace most existing revenue recognition guidance in GAAP when it becomes effective. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted beginning in the first quarter of fiscal 2018. The standard permits the use of either the retrospective or cumulative effect transition method. The Partnership is in the process of evaluating the effect that ASU 2014-09 will have on its revenue streams, consolidated financial statements and related disclosures. The Partnership has not yet selected a transition method, nor does it intend to early adopt.

In July 2015, the FASB issued ASU No. 2015-11, Simplifying the Measurement of Inventory. The update changes the measurement principle for inventory from the lower of cost or market to the lower of cost and net realizable value. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2018, with early adoption permitted. The Partnership does not expect ASU No. 2015-11 to have a material impact on its consolidated financial statements and related disclosures.

In February 2016, the FASB issued ASU No. 2016-02, Leases. The update requires all leases with a term greater than twelve months to be recognized on the balance sheet by calculating the discounted present value of such leases and accounting for them through a right-of-use asset and an offsetting lease liability, and the disclosure of key information pertaining to leasing arrangements. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2020, with early adoption permitted. The Partnership does not intend to early adopt. The Partnership is continuing to evaluate the effect that ASU No. 2016-02 could have on its consolidated financial statements and related disclosures, but has not yet selected a transition method. The new guidance will materially change how we account for operating leases for office space, trucks and other equipment. Upon adoption, we expect to recognize discounted right-of-use assets and offsetting lease liabilities related to our operating leases of office space, trucks and other equipment. As of June 30, 2017, the undiscounted future minimum lease payments through 2032 for such operating leases are approximately $131.8 million, but what the range of reasonable discount rates will be at the time of adoption and what amount of leasing activity is expected between June 30, 2017, and the date of adoption, are currently unknown. For this reason we are unable to estimate the discounted right-of-use assets and lease liabilities as of the date of adoption.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments – Credit Losses. The update broadens the information that an entity should consider in developing expected credit loss estimates, eliminates the probable initial recognition threshold, and allows for the immediate recognition of the full amount of expected credit losses. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2021, with early adoption permitted in the first quarter of fiscal 2020. The Partnership is evaluating the effect that ASU No. 2016-13 will have on its consolidated financial statements and related disclosures, but has not yet determined the timing of adoption.

In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flow (Topic 230): Classification of Certain Cash Receipts and Cash Payments. The update addresses the issues of debt prepayment or debt extinguishment costs, settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate owned life insurance policies, distributions received from equity method investees, beneficial interests in securitization transactions, and separately identifiable cash flows and application of the predominance principle. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2016-15 to have a material impact on its consolidated financial statements and related disclosures.

In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the definition of a business. The update clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2017-01 to have a material impact on its consolidated financial statements and related disclosures.

In January 2017, the FASB issued ASU No. 2017-04, Intangibles – Goodwill and Other (Topic 230): Simplifying the test for goodwill impairment. The update simplifies how an entity is required to test goodwill for impairment. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value, but not exceed the total amount of goodwill allocated to the reporting unit. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2021, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2017-04 to have a material impact on its consolidated financial statements and related disclosures.

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Common Unit Repurchase and Retirement

9 Months Ended

Jun. 30, 2017

Common Unit Repurchase and Retirement

3) Common Unit Repurchase and Retirement

In July 2012, the Board authorized the repurchase of up to 3.0 million of the Partnership’s Common Units (“Plan III”). In July 2013, the Board authorized the repurchase of an additional 1.9 million Common Units under Plan III. 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. There is no guarantee of the exact number of units that will be purchased under the program and the Partnership may discontinue purchases at any time. The program does not have a time limit. The Board may also approve additional purchases of units from time to time in private transactions. 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.

Under the Partnership’s third amended and restated credit agreement dated July 30, 2015, in order to repurchase Common Units we must maintain Availability (as defined in the amended and restated credit agreement) of $45 million, 15.0% of the facility size of $300 million (assuming the non-seasonal aggregate commitment is in effect) 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. The Partnership was in compliance with this covenant as of June 30, 2017.

The following table shows repurchases under Plan III.

(in thousands, except per unit amounts) Period	Total Number of Units Purchased (a)		Average Price Paid per Unit (b)		Maximum Number of Units that May Yet Be Purchased
Plan III - Number of units authorized						4,894
Private transaction - Number of units authorized						2,450
						7,344
Plan III - Fiscal years 2012 to 2016 total (c)		5,137	$	5.78		2,207
Plan III - Fiscal year 2017 total		—	$	—		2,207

(a) Units were repurchased as part of a publicly announced program, except as noted in a private transaction.

(b) Amounts include repurchase costs.

(c) Includes 2.45 million common units acquired in a private transaction.

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Derivatives and Hedging-Disclosures and Fair Value Measurements

9 Months Ended

Jun. 30, 2017

Derivatives and Hedging-Disclosures and Fair Value Measurements

4) Derivatives and Hedging—Disclosures and Fair Value Measurements

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 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, priced purchase commitments and internal fuel usage. The Partnership has elected not to designate its derivative instruments as hedging derivatives, but rather as economic hedges whose change in fair value is recognized in its statement of operations in the line item (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 June 30, 2017, to hedge a substantial majority of the purchase price associated with heating oil gallons anticipated to be sold to its price-protected customers, the Partnership held the following derivative instruments that settle in future months to match anticipated sales: 9.0 million gallons of swap contracts, 3.6 million gallons of call options, 5.0 million gallons of put options, and 55.0 million net gallons of synthetic call options. To hedge the inter-month differentials for its price-protected customers, its physical inventory on hand and inventory in transit, the Partnership, as of June 30, 2017, had 1.3 million gallons of long swap contracts, 53.3 million gallons of long future contracts, and 67.7 million gallons of short future contracts that settle in future months. In addition to the above, to lock-in the differential between high sulfur home heating oil and ultra low sulfur diesel, the Partnership as of June 30, 2017, had 0.4 million gallons of spread contracts (simultaneous long and short positions). To hedge its internal fuel usage and other related activities for fiscal 2017, the Partnership, as of June 30, 2017, had 6.5 million gallons of swap contracts that settle in future months.

As of June 30, 2016, to hedge a substantial majority of the purchase price associated with heating oil gallons anticipated to be sold to its price-protected customers, the Partnership held the following derivative instruments that settle in future months to match anticipated sales: 6.6 million gallons of swap contracts, 4.5 million gallons of call options, 4.1 million gallons of put options, and 60.0 million net gallons of synthetic call options. To hedge the inter-month differentials for its price-protected customers, its physical inventory on hand and inventory in transit, the Partnership, as of June 30, 2016, had 1.1 million gallons of long swap contracts, 54.0 million gallons of long future contracts, and 70.1 million gallons of short future contracts that settle in future months. In addition to the previously described hedging instruments, to lock-in the differential between high sulfur home heating oil and ultra low sulfur diesel, the Partnership as of June 30, 2016, had 0.7 million gallons of spread contracts (simultaneous long and short positions). To hedge its internal fuel usage and other related activities for fiscal 2016, the Partnership, as of June 30, 2016, had 5.9 million gallons of swap contracts that settle in future months.

The Partnership’s derivative instruments are with the following counterparties: Bank of America, N.A., Bank of Montreal, Cargill, Inc., Citibank, N.A., JPMorgan Chase Bank, N.A., Key Bank, N.A., Munich Re Trading LLC, Regions Financial Corporation, Societe Generale, and Wells Fargo Bank, N.A. The Partnership 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 Partnership generally does not receive cash collateral from its counterparties and does not restrict the use of cash collateral it maintains at counterparties. At June 30, 2017, the aggregate cash posted as collateral in the normal course of business at counterparties was $0.5 million, which was recorded in prepaid expenses and other current assets. Positions with counterparties who are also parties to our credit agreement are collateralized under that facility. As of June 30, 2017, $4.9 million of hedge positions were secured under the credit facility.

FASB ASC 820-10 Fair Value Measurements and Disclosures, 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 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 Partnership’s Level 2 derivative assets and liabilities represent the fair value of commodity 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 Partnership 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 Partnership. The Partnership’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 Partnership are based on a combination of the NYMEX published market prices and other inputs, including such factors as present value, volatility and duration.

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

(In thousands)					Fair Value Measurements at Reporting Date Using:
Derivatives Not Designated as Hedging Instruments					Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs
Under FASB ASC 815-10	Balance Sheet Location	Total			Level 1			Level 2
Asset Derivatives at June 30, 2017
Commodity contracts	Fair asset and fair liability value of derivative instruments	$	8,378		$	—		$	8,378
Commodity contracts	Long-term derivative assets included in the deferred charges and other assets, net and other long-term liabilities balances		1,096			—			1,096
Commodity contract assets at June 30, 2017		$	9,474		$	—		$	9,474
Liability Derivatives at June 30, 2017
Commodity contracts	Fair liability and fair asset value of derivative instruments	$	(13,138	)	$	—		$	(13,138	)
Commodity contracts	Cash collateral		—			—			—
Commodity contracts	Long-term derivative liabilities included in the deferred charges and other assets, net and other long-term liabilities balances		(1,232	)		—			(1,232	)
Commodity contract liabilities at June 30, 2017		$	(14,370	)	$	—		$	(14,370	)
Asset Derivatives at September 30, 2016
Commodity contracts	Fair asset and fair liability value of derivative instruments	$	11,692		$	—		$	11,692
Commodity contracts	Long-term derivative assets included in the other long-term liabilities balance		1,369			481			888
Commodity contract assets at September 30, 2016		$	13,061		$	481		$	12,580
Liability Derivatives at September 30, 2016
Commodity contracts	Fair liability and fair asset value of derivative instruments	$	(9,990	)	$	(1,603	)	$	(8,387	)
Commodity contracts	Cash collateral		—			—			—
Commodity contracts	Long-term derivative liabilities included in the other long-term liabilities balance		(565	)		(484	)		(81	)
Commodity contract liabilities at September 30, 2016		$	(10,555	)	$	(2,087	)	$	(8,468	)

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

(In thousands)									Gross Amounts Not Offset in the Statement of Financial Position
Offsetting of Financial Assets (Liabilities) and Derivative Assets (Liabilities)	Gross Assets Recognized		Gross Liabilities Offset in the Statement of Financial Position			Net Assets (Liabilities) Presented in the Statement of Financial Position			Financial Instruments		Cash Collateral Received		Net Amount
Fair asset value of derivative instruments	$	—	$	—		$	—		$	—	$	—	$	—
Long-term derivative assets included in deferred charges and other assets, net		174		(165	)		9			—		—		9
Fair liability value of derivative instruments		8,378		(13,138	)		(4,760	)		—		—		(4,760	)
Long-term derivative liabilities included in other long-term liabilities, net		922		(1,067	)		(145	)						(145	)
Total at June 30, 2017	$	9,474	$	(14,370	)	$	(4,896	)	$	—	$	—	$	(4,896	)
Fair asset value of derivative instruments	$	7,716	$	(3,729	)	$	3,987		$	—	$	—	$	3,987
Long-term derivative assets included in other long-term assets, net		888		(81	)		807			—		—		807
Fair liability value of derivative instruments		3,976		(6,261	)		(2,285	)		—		—		(2,285	)
Long-term derivative liabilities included in other long-term liabilities, net		481		(484	)		(3	)		—		—		(3	)
Total at September 30, 2016	$	13,061	$	(10,555	)	$	2,506		$	—	$	—	$	2,506

(In thousands)
The Effect of Derivative Instruments on the Statement of Operations
		Amount of (Gain) or Loss Recognized
Derivatives Not Designated as Hedging Instruments Under FASB ASC 815-10	Location of (Gain) or Loss Recognized in Income on Derivative	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016			Nine Months Ended June 30, 2017			Nine Months Ended June 30, 2016
Commodity contracts	Cost of product (a)	$	1,092	$	8,177		$	4,073		$	16,978
Commodity contracts	Cost of installations and service (a)	$	—	$	72		$	(526	)	$	848
Commodity contracts	Delivery and branch expenses (a)	$	27	$	150		$	(422	)	$	1,029
Commodity contracts	(Increase) / decrease in the fair value of derivative instruments (b)	$	3,135	$	(11,283	)	$	7,026		$	(20,071	)

(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.

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Inventories

9 Months Ended

Jun. 30, 2017

Inventories

5) Inventories

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

	June 30, 2017		September 30, 2016
Product	$	21,364	$	25,419
Parts and equipment		21,058		20,475
Total inventory	$	42,422	$	45,894

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Property and Equipment

9 Months Ended

Jun. 30, 2017

Property and Equipment

6) Property and Equipment

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

	June 30, 2017		September 30, 2016
Property and equipment	$	195,181	$	184,079
Less: accumulated depreciation		120,690		113,669
Property and equipment, net	$	74,491	$	70,410

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Business Combinations

9 Months Ended

Jun. 30, 2017

Business Combinations

7) Business Combinations

Through the third quarter of fiscal 2017, the Partnership acquired three heating oil dealers, a propane dealer and a plumbing service provider for an aggregate purchase price of approximately $16.0 million; $14.5 million in cash and $1.5 million of deferred liabilities (including $0.6 million of contingent consideration). The gross purchase price was allocated $9.3 million to intangible assets, $2.5 million to goodwill, $5.0 million to fixed assets and received credit for a negative working capital position of $0.8 million. The acquired companies’ operating results are included in the Partnership’s consolidated financial statements starting on their respective acquisition dates, and are not material to the Partnership’s financial condition, results of operations, or cash flows.

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Goodwill and Intangibles, net

9 Months Ended

Jun. 30, 2017

Goodwill and Intangibles, net

8) Goodwill and Intangibles, net

Goodwill

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

Balance as of September 30, 2016	$	212,760
Fiscal year 2017 business combinations		2,502
Balance as of June 30, 2017	$	215,262

Intangibles, net

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

	June 30, 2017						September 30, 2016
	Gross						Gross
	Carrying		Accum.				Carrying		Accum.
	Amount		Amortization		Net		Amount		Amortization		Net
Customer lists	$	334,605	$	261,017	$	73,588	$	327,388	$	250,427	$	76,961
Trade names and other intangibles		29,210		8,278		20,932		27,134		6,439		20,695
Total	$	363,815	$	269,295	$	94,520	$	354,522	$	256,866	$	97,656

Amortization expense for intangible assets was $12.4 million for the nine months ended June 30, 2017, compared to $11.5 million for the nine months ended June 30, 2016.

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Long-Term Debt and Bank Facility Borrowings

9 Months Ended

Jun. 30, 2017

Long-Term Debt and Bank Facility Borrowings

9) Long-Term Debt and Bank Facility Borrowings

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

	June 30,				September 30,
	2017				2016
	Carrying				Carrying
	Amount		Fair Value (a)		Amount		Fair Value (a)
Revolving Credit Facility Borrowings	$	—	$	—	$	—	$	—
Senior Secured Term Loan (b)	$	78,155	$	78,800	$	91,641	$	92,500
Total debt	$	78,155	$	78,800	$	91,641	$	92,500
Total short-term portion of debt	$	10,000	$	10,000	$	16,200	$	16,200
Total long-term portion of debt	$	68,155	$	68,800	$	75,441	$	76,300

(a) The face amount of the Partnership’s variable rate long-term debt approximates fair value.

(b) Carrying amounts are net of unamortized debt issuance costs of $0.6 million as of June 30, 2017, and $0.9 million as of September 30, 2016.

On July 30, 2015, the Partnership entered into a third amended and restated asset-based credit agreement with a bank syndicate comprised of thirteen participants, which enables the Partnership to borrow up to $300 million ($450 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 $100 million five-year senior secured term loan (the “Term Loan”), allows for the issuance of up to $100 million in letters of credit, and has a maturity date of July 30, 2020.

The Partnership can increase the revolving credit facility size by $100 million without the consent of the bank group. However, the bank group is not obligated to fund the $100 million increase. If the bank group elects not to fund the increase, the Partnership can add additional lenders to the group, with the consent of the Agent (as defined in the credit agreement), which shall not be unreasonably withheld. Obligations under the third amended and restated credit facility are guaranteed by the Partnership and its subsidiaries and are secured by liens on substantially all of the Partnership’s assets including accounts receivable, inventory, general intangibles, real property, fixtures and equipment.

All amounts outstanding under the third amended and restated revolving credit facility become due and payable on the facility termination date of July 30, 2020. The Term Loan is repayable in quarterly payments of $2.5 million, plus an annual payment equal to 25% of the annual Excess Cash Flow as defined in the agreement (an amount not to exceed $15 million annually), less certain voluntary prepayments made during the year, with final payment at maturity.

The interest rate on the third amended and restated revolving credit facility and the Term Loan is based on a margin over LIBOR or a base rate. At June 30, 2017, the effective interest rate on the Term Loan was approximately 4.01%.

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 third amended and restated credit agreement requires the Partnership to meet certain financial covenants, including a fixed charge coverage ratio (as defined in the credit agreement) of not less than 1.1 as long as the Term Loan is outstanding or revolving credit facility availability is less than 12.5% of the facility size. In addition, as long as the Term Loan is outstanding, a senior secured leverage ratio at any time cannot be more than 3.0 as calculated during the quarters ending June or September, and at any time no more than 4.5 as calculated during the quarters ending December or March.

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

At June 30, 2017, $78.8 million of the Term Loan was outstanding, no amount was outstanding under the revolving credit facility, $4.9 million of hedge positions were secured under the credit agreement, and $48.2 million of letters of credit were issued and outstanding. At September 30, 2016, $92.5 million of the Term Loan was outstanding, no amount was outstanding under the revolving credit facility, $0.3 million of hedge positions were secured under the credit agreement, and $50.6 million of letters of credit were issued and outstanding.

At June 30, 2017, availability was $160.3 million, and the Partnership was in compliance with the fixed charge coverage ratio and the senior secured leverage ratio. At September 30, 2016, availability was $163.4 million, and the Partnership was in compliance with the fixed charge coverage ratio and the senior secured leverage ratio.

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Income Taxes

9 Months Ended

Jun. 30, 2017

Income Taxes

10) Income Taxes

Since Star Gas Partners is organized as a master limited partnership, it is not subject to tax at its entity level for Federal and state income tax purposes. However, Star Gas Partners’ income is derived from its corporate subsidiaries, and these entities do incur Federal and state income taxes relating to their respective corporate subsidiaries, which are reflected in these financial statements. For the corporate subsidiaries of Star Gas Partners, a consolidated Federal income tax return is filed.

Income and losses of Star Gas Partners are allocated directly to the individual partners. Even though Star Gas Partners will generate non-qualifying Master Limited Partnership income through its corporate subsidiaries, cash received by Star Gas Partners from its corporate subsidiaries is generally included in the determination of qualified Master Limited Partnership income. All or a portion of such cash could be taxable as dividend income or as a capital gain to the individual partners. This could be the case even if Star Gas Partners used the cash received from its corporate subsidiaries for purposes such as the repurchase of Common Units, other types of capital transactions, or paying its own expenses rather than for distributions to its individual partners.

The accompanying financial statements are reported on a fiscal year; however, Star Gas Partners and its corporate subsidiaries file Federal and state income tax returns on a calendar year.

The current and deferred income tax expenses (benefits) for the three and nine months ended June 30, 2017, and 2016, are as follows:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(in thousands)	2017			2016			2017		2016
Income (loss) before income taxes	$	(21,766	)	$	(4,993	)	$	76,368	$	110,595
Current tax expense (benefit)		(5,764	)		(6,759	)		27,270		33,268
Deferred tax expense (benefit)		(2,670	)	$	5,004			4,451	$	13,298
Total tax expense (benefit)	$	(8,434	)	$	(1,755	)	$	31,721	$	46,566

As of January 1, 2017, Star Acquisitions, Inc., a wholly-owned subsidiary of the Partnership, had an estimated Federal net operating loss carry forward (“NOLs”) of approximately $1.6 million. The Federal NOLs, which will expire between 2018 and 2024, are generally available to offset any future taxable income but are also subject to annual limitations of between $1.0 million and $2.2 million.

At June 30, 2017, we did not 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, Pennsylvania we have four years that are subject to examination. In the state tax jurisdictions 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.

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Supplemental Disclosure of Cash Flow Information

9 Months Ended

Jun. 30, 2017

Supplemental Disclosure of Cash Flow Information

11) Supplemental Disclosure of Cash Flow Information

	Nine Months Ended
	June 30,
(in thousands)	2017		2016
Cash paid during the period for:
Income taxes, net	$	4,116	$	15,411
Interest	$	6,002	$	5,082
Non-cash operating activities:
Increase in interest expense—amortization of deferred charges on senior secured term loan	$	225	$	214

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Commitments and Contingencies

9 Months Ended

Jun. 30, 2017

Commitments and Contingencies

12) Commitments and Contingencies

On February 18, 2016, a civil action was filed in the United States District Court, District of New Jersey, entitled M. Norman Donnenfeld v. Petro Home Services, Petro Holdings Inc. and Petro, Inc., Civil Action Number 2:16-cv-00882 JMV-JBC, against Petro Home Services which is a brand name, Petro Holdings Inc. and Petro, Inc. Plaintiff alleged he did not receive expected contractual benefits under his protected price plan contract when oil prices fell and asserted various claims for relief including breach of contract, violation of the New York General Business Law and fraud. The Plaintiff also sought to have a class certified of all customers of the defendants in the United States who entered into protected price plan contracts and were denied the same contractual benefits and to be appointed to represent them. The Plaintiff sought compensatory, punitive and other damages in unspecified amounts. On May 9, 2016, the Partnership filed a motion to dismiss the complaint for lack of personal jurisdiction and failure to state a claim for relief and to strike the class action allegations. On March 24, 2017, the motion to dismiss the complaint was granted, for failure to state a claim and for lack of personal jurisdiction but Plaintiff was given 30 days to attempt to replead.

Instead of filing an amended complaint, on April 18, 2017, Plaintiff commenced a new putative class action in the United States District Court for the Eastern District of New York, entitled M. Norman Donnenfeld v. Petro, Inc., Civil Action Number 2:17-cv-02310-JFB-SIL. The new complaint names Petro, Inc. d/b/a Petro Home Services as the sole defendant. The allegations and claims in the new complaint are substantially similar to those in the prior complaint filed in the District of New Jersey. No class has yet been certified in this action. The Partnership believes the allegations lack merit and intends to vigorously defend the action; at this time we cannot assess the potential outcome or materiality of this matter.

The Partnership’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 Partnership is a defendant in various legal proceedings and litigation. The Partnership 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 Partnership’s results of operations, financial position or liquidity.

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 current and potential future claims, legal proceedings and litigation, including the above mentioned action, 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.

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Earnings Per Limited Partner Unit

9 Months Ended

Jun. 30, 2017

Earnings Per Limited Partner Unit

13) Earnings Per Limited Partner Unit

Income per limited partner unit is computed in accordance with FASB ASC 260-10-05 Earnings Per Share, Master Limited Partnerships (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 result 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 performed, in which the Partnership’s contractual participation rights are taken into account.

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

	Three Months Ended						Nine Months Ended
Basic and Diluted Earnings Per Limited Partner:	June 30,						June 30,
(in thousands, except per unit data)	2017			2016			2017		2016
Net income (loss)	$	(13,332	)	$	(3,238	)	$	44,647	$	64,029
Less General Partner’s interest in net income		(79	)		(19	)		259		362
Net income (loss) available to limited partners		(13,253	)		(3,219	)		44,388		63,667
Less dilutive impact of theoretical distribution of earnings under FASB ASC 260-10-45-60		—			—			5,420		9,313
Limited Partner’s interest in net income (loss) under FASB ASC 260-10-45-60	$	(13,253	)	$	(3,219	)	$	38,968	$	54,354
Per unit data:
Basic and diluted net income (loss) available to limited partners	$	(0.24	)	$	(0.06	)	$	0.79	$	1.11
Less dilutive impact of theoretical distribution of earnings under FASB ASC 260-10-45-60		—			—			0.09		0.16
Limited Partner’s interest in net income (loss) under FASB ASC 260-10-45-60	$	(0.24	)	$	(0.06	)	$	0.70	$	0.95
Weighted average number of Limited Partner units outstanding		55,888			57,188			55,888		57,237

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Subsequent Events

9 Months Ended

Jun. 30, 2017

Subsequent Events

14) Subsequent Events

Quarterly Distribution Declared

In July 2017, we declared a quarterly distribution of $0.11 per unit, or $0.44 per unit on an annualized basis, on all Common Units with respect to the second quarter of fiscal 2017, payable on August 8, 2017, to holders of record on July 31, 2017. In accordance with our Partnership Agreement, the amount of distributions in excess of the minimum quarterly distribution of $0.0675, are distributed 90% to Common Unit holders and 10% to the General Partner unit holders (until certain distribution levels are met), subject to the management incentive compensation plan. As a result, $6.1 million will be paid to the Common Unit holders, $0.2 million to the General Partner unit holders (including $0.1 million of incentive distribution as provided in our Partnership Agreement) and $0.1 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.

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Jun. 30, 2017

Basis of Presentation

Basis of Presentation

The Consolidated Financial Statements include the accounts of Star Gas Partners 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 and cash flows for the nine month period ended June 30, 2017, 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 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 and should be read in conjunction with the financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended September 30, 2016.

Comprehensive Income (Loss)

Comprehensive Income (Loss)

Comprehensive income (loss) is comprised of net income (loss) and other comprehensive income (loss). Other comprehensive income (loss) consists of the unrealized gain (loss) amortization on the Partnership’s pension plan obligation for its two frozen defined benefit pension plans and the corresponding tax effect.

Cash, Cash Equivalents, and Restricted Cash

Cash, cash equivalents, and restricted cash

At June 30, 2017, the $94.8 million of cash, cash equivalents, and restricted cash on the condensed consolidated statement of cash flows is composed of $94.6 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.

Investments

Investments

The investments are held by our captive insurance company in an irrevocable trust as collateral for workers’ compensation and automobile liability claims incurred and expected to be incurred in fiscal 2017. The collateral is required by a third party insurance carrier that insures per claim amounts above a set deductible. 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, the collateral is not expected to be used to pay obligations within the next twelve months.

Investments are currently comprised of $10.3 million of Level 1 debt securities and $1.4 million of mutual funds measured at net asset value.

Weather Hedge Contract

Weather Hedge Contract

To partially mitigate the effect of weather on cash flows, the Partnership 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.

For fiscal years 2016 and 2017, the Partnership had weather hedge contracts that cover the five month period from November 1, through March 31, taken as a whole, for each respective fiscal year. The ultimate amount due to the Partnership (if any) was based on the entire five month accumulated calculation for the hedge period and had a maximum payout of $12.5 million for each respective fiscal year. In accordance with ASC 815-45-15, as of December 31, 2015, the Partnership recorded a credit of $12.5 million during fiscal 2016 under this contract that reduced delivery and branch expenses. No credit was recorded during the nine months ended June 30, 2017.

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

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

As of June 30, 2017, we had $0.2 million and $17.4 million balances 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. Based on the borrowing rates currently available to the Partnership for long-term financing of a similar maturity, the fair value of the NETTI Fund withdrawal liability as of June 30, 2017 was $22.2 million. 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

Recently Adopted Accounting Pronouncements

In April 2015, the FASB issued Accounting Standards Update (“ASU”) No. 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The update requires debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability instead of being presented as an asset. The Partnership retrospectively adopted the ASU effective December 31, 2016. As a result of the adoption, certain prior year balances (September 30, 2016) changed to conform to the current year presentation as follows: deferred charges and other assets, net decreased from $11.9 million to $11.1 million and long-term debt decreased from $76.3 million to $75.4 million.

In September 2015, the FASB issued ASU No. 2015-16, Simplifying the Accounting for Measurement-Period Adjustments, which requires an acquiring entity to recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. The acquiring entity is required to record, in the same period’s financial statements, the effect on earnings of changes in depreciation, amortization, or other income effects, if any, as a result of the change to the provisional amounts, calculated as if the accounting had been completed at the acquisition date. In addition, the acquiring entity is to present separately on the face of its income statement or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods as if the adjustment to the provisional amounts had been recognized as of the acquisition date. The Partnership adopted the ASU effective December 31, 2016. The adoption of ASU No. 2015-16 did not have an impact on the Partnership’s consolidated financial statements and related disclosures.

In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flow (Topic 230): Restricted cash. The update requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The Partnership adopted the ASU effective December 31, 2016. The adoption of ASU No. 2016-18 did not have a material impact on the Partnership’s consolidated financial statements and related disclosures.

Recently Issued Accounting Pronouncements

Recently Issued Accounting Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The FASB has also issued several updates to ASU 2014-09. This ASU will replace most existing revenue recognition guidance in GAAP when it becomes effective. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted beginning in the first quarter of fiscal 2018. The standard permits the use of either the retrospective or cumulative effect transition method. The Partnership is in the process of evaluating the effect that ASU 2014-09 will have on its revenue streams, consolidated financial statements and related disclosures. The Partnership has not yet selected a transition method, nor does it intend to early adopt.

In July 2015, the FASB issued ASU No. 2015-11, Simplifying the Measurement of Inventory. The update changes the measurement principle for inventory from the lower of cost or market to the lower of cost and net realizable value. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2018, with early adoption permitted. The Partnership does not expect ASU No. 2015-11 to have a material impact on its consolidated financial statements and related disclosures.

In February 2016, the FASB issued ASU No. 2016-02, Leases. The update requires all leases with a term greater than twelve months to be recognized on the balance sheet by calculating the discounted present value of such leases and accounting for them through a right-of-use asset and an offsetting lease liability, and the disclosure of key information pertaining to leasing arrangements. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2020, with early adoption permitted. The Partnership does not intend to early adopt. The Partnership is continuing to evaluate the effect that ASU No. 2016-02 could have on its consolidated financial statements and related disclosures, but has not yet selected a transition method. The new guidance will materially change how we account for operating leases for office space, trucks and other equipment. Upon adoption, we expect to recognize discounted right-of-use assets and offsetting lease liabilities related to our operating leases of office space, trucks and other equipment. As of June 30, 2017, the undiscounted future minimum lease payments through 2032 for such operating leases are approximately $131.8 million, but what the range of reasonable discount rates will be at the time of adoption and what amount of leasing activity is expected between June 30, 2017, and the date of adoption, are currently unknown. For this reason we are unable to estimate the discounted right-of-use assets and lease liabilities as of the date of adoption.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments – Credit Losses. The update broadens the information that an entity should consider in developing expected credit loss estimates, eliminates the probable initial recognition threshold, and allows for the immediate recognition of the full amount of expected credit losses. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2021, with early adoption permitted in the first quarter of fiscal 2020. The Partnership is evaluating the effect that ASU No. 2016-13 will have on its consolidated financial statements and related disclosures, but has not yet determined the timing of adoption.

In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flow (Topic 230): Classification of Certain Cash Receipts and Cash Payments. The update addresses the issues of debt prepayment or debt extinguishment costs, settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate owned life insurance policies, distributions received from equity method investees, beneficial interests in securitization transactions, and separately identifiable cash flows and application of the predominance principle. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2016-15 to have a material impact on its consolidated financial statements and related disclosures.

In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the definition of a business. The update clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2019, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2017-01 to have a material impact on its consolidated financial statements and related disclosures.

In January 2017, the FASB issued ASU No. 2017-04, Intangibles – Goodwill and Other (Topic 230): Simplifying the test for goodwill impairment. The update simplifies how an entity is required to test goodwill for impairment. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value, but not exceed the total amount of goodwill allocated to the reporting unit. This new guidance is effective for our annual reporting period beginning in the first quarter of fiscal 2021, with early adoption permitted. The Partnership has not determined the timing of adoption, but does not expect ASU 2017-04 to have a material impact on its consolidated financial statements and related disclosures.

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Common Unit Repurchase and Retirement (Tables)

9 Months Ended

Jun. 30, 2017

Partnership's Repurchase Activities

The following table shows repurchases under Plan III.

(in thousands, except per unit amounts) Period	Total Number of Units Purchased (a)		Average Price Paid per Unit (b)		Maximum Number of Units that May Yet Be Purchased
Plan III - Number of units authorized						4,894
Private transaction - Number of units authorized						2,450
						7,344
Plan III - Fiscal years 2012 to 2016 total (c)		5,137	$	5.78		2,207
Plan III - Fiscal year 2017 total		—	$	—		2,207

(a) Units were repurchased as part of a publicly announced program, except as noted in a private transaction.

(b) Amounts include repurchase costs.

(c) Includes 2.45 million common units acquired in a private transaction.

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Derivatives and Hedging-Disclosures and Fair Value Measurements (Tables)

9 Months Ended

Jun. 30, 2017

Partnership's Financial Assets and Liabilities Measured at Fair Value on Recurring Basis

The Partnership’s financial assets and liabilities measured at fair value on a recurring basis are listed on the following table.

(In thousands)					Fair Value Measurements at Reporting Date Using:
Derivatives Not Designated as Hedging Instruments					Quoted Prices in Active Markets for Identical Assets			Significant Other Observable Inputs
Under FASB ASC 815-10	Balance Sheet Location	Total			Level 1			Level 2
Asset Derivatives at June 30, 2017
Commodity contracts	Fair asset and fair liability value of derivative instruments	$	8,378		$	—		$	8,378
Commodity contracts	Long-term derivative assets included in the deferred charges and other assets, net and other long-term liabilities balances		1,096			—			1,096
Commodity contract assets at June 30, 2017		$	9,474		$	—		$	9,474
Liability Derivatives at June 30, 2017
Commodity contracts	Fair liability and fair asset value of derivative instruments	$	(13,138	)	$	—		$	(13,138	)
Commodity contracts	Cash collateral		—			—			—
Commodity contracts	Long-term derivative liabilities included in the deferred charges and other assets, net and other long-term liabilities balances		(1,232	)		—			(1,232	)
Commodity contract liabilities at June 30, 2017		$	(14,370	)	$	—		$	(14,370	)
Asset Derivatives at September 30, 2016
Commodity contracts	Fair asset and fair liability value of derivative instruments	$	11,692		$	—		$	11,692
Commodity contracts	Long-term derivative assets included in the other long-term liabilities balance		1,369			481			888
Commodity contract assets at September 30, 2016		$	13,061		$	481		$	12,580
Liability Derivatives at September 30, 2016
Commodity contracts	Fair liability and fair asset value of derivative instruments	$	(9,990	)	$	(1,603	)	$	(8,387	)
Commodity contracts	Cash collateral		—			—			—
Commodity contracts	Long-term derivative liabilities included in the other long-term liabilities balance		(565	)		(484	)		(81	)
Commodity contract liabilities at September 30, 2016		$	(10,555	)	$	(2,087	)	$	(8,468	)

Partnership's Derivatives Assets (Liabilities) Offset by Counterparty

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

(In thousands)									Gross Amounts Not Offset in the Statement of Financial Position
Offsetting of Financial Assets (Liabilities) and Derivative Assets (Liabilities)	Gross Assets Recognized		Gross Liabilities Offset in the Statement of Financial Position			Net Assets (Liabilities) Presented in the Statement of Financial Position			Financial Instruments		Cash Collateral Received		Net Amount
Fair asset value of derivative instruments	$	—	$	—		$	—		$	—	$	—	$	—
Long-term derivative assets included in deferred charges and other assets, net		174		(165	)		9			—		—		9
Fair liability value of derivative instruments		8,378		(13,138	)		(4,760	)		—		—		(4,760	)
Long-term derivative liabilities included in other long-term liabilities, net		922		(1,067	)		(145	)						(145	)
Total at June 30, 2017	$	9,474	$	(14,370	)	$	(4,896	)	$	—	$	—	$	(4,896	)
Fair asset value of derivative instruments	$	7,716	$	(3,729	)	$	3,987		$	—	$	—	$	3,987
Long-term derivative assets included in other long-term assets, net		888		(81	)		807			—		—		807
Fair liability value of derivative instruments		3,976		(6,261	)		(2,285	)		—		—		(2,285	)
Long-term derivative liabilities included in other long-term liabilities, net		481		(484	)		(3	)		—		—		(3	)
Total at September 30, 2016	$	13,061	$	(10,555	)	$	2,506		$	—	$	—	$	2,506

Partnership's Derivatives Assets (Liabilities) Offset by Counterparty

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

(In thousands)									Gross Amounts Not Offset in the Statement of Financial Position
Offsetting of Financial Assets (Liabilities) and Derivative Assets (Liabilities)	Gross Assets Recognized		Gross Liabilities Offset in the Statement of Financial Position			Net Assets (Liabilities) Presented in the Statement of Financial Position			Financial Instruments		Cash Collateral Received		Net Amount
Fair asset value of derivative instruments	$	—	$	—		$	—		$	—	$	—	$	—
Long-term derivative assets included in deferred charges and other assets, net		174		(165	)		9			—		—		9
Fair liability value of derivative instruments		8,378		(13,138	)		(4,760	)		—		—		(4,760	)
Long-term derivative liabilities included in other long-term liabilities, net		922		(1,067	)		(145	)						(145	)
Total at June 30, 2017	$	9,474	$	(14,370	)	$	(4,896	)	$	—	$	—	$	(4,896	)
Fair asset value of derivative instruments	$	7,716	$	(3,729	)	$	3,987		$	—	$	—	$	3,987
Long-term derivative assets included in other long-term assets, net		888		(81	)		807			—		—		807
Fair liability value of derivative instruments		3,976		(6,261	)		(2,285	)		—		—		(2,285	)
Long-term derivative liabilities included in other long-term liabilities, net		481		(484	)		(3	)		—		—		(3	)
Total at September 30, 2016	$	13,061	$	(10,555	)	$	2,506		$	—	$	—	$	2,506

Partnership's Effect on Derivative Instruments on the Statement of Operations

(In thousands)
The Effect of Derivative Instruments on the Statement of Operations
		Amount of (Gain) or Loss Recognized
Derivatives Not Designated as Hedging Instruments Under FASB ASC 815-10	Location of (Gain) or Loss Recognized in Income on Derivative	Three Months Ended June 30, 2017		Three Months Ended June 30, 2016			Nine Months Ended June 30, 2017			Nine Months Ended June 30, 2016
Commodity contracts	Cost of product (a)	$	1,092	$	8,177		$	4,073		$	16,978
Commodity contracts	Cost of installations and service (a)	$	—	$	72		$	(526	)	$	848
Commodity contracts	Delivery and branch expenses (a)	$	27	$	150		$	(422	)	$	1,029
Commodity contracts	(Increase) / decrease in the fair value of derivative instruments (b)	$	3,135	$	(11,283	)	$	7,026		$	(20,071	)

(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.

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Inventories (Tables)

9 Months Ended

Jun. 30, 2017

Components of Inventory

The components of inventory were as follows (in thousands):

	June 30, 2017		September 30, 2016
Product	$	21,364	$	25,419
Parts and equipment		21,058		20,475
Total inventory	$	42,422	$	45,894

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Property and Equipment (Tables)

9 Months Ended

Jun. 30, 2017

Property and Equipment

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

	June 30, 2017		September 30, 2016
Property and equipment	$	195,181	$	184,079
Less: accumulated depreciation		120,690		113,669
Property and equipment, net	$	74,491	$	70,410

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Goodwill and Intangibles, net (Tables)

9 Months Ended

Jun. 30, 2017

Summary of Changes in the Partnership's Goodwill

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

Balance as of September 30, 2016	$	212,760
Fiscal year 2017 business combinations		2,502
Balance as of June 30, 2017	$	215,262

Intangible Assets Subject to Amortization

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

	June 30, 2017						September 30, 2016
	Gross						Gross
	Carrying		Accum.				Carrying		Accum.
	Amount		Amortization		Net		Amount		Amortization		Net
Customer lists	$	334,605	$	261,017	$	73,588	$	327,388	$	250,427	$	76,961
Trade names and other intangibles		29,210		8,278		20,932		27,134		6,439		20,695
Total	$	363,815	$	269,295	$	94,520	$	354,522	$	256,866	$	97,656

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Long-Term Debt and Bank Facility Borrowings (Tables)

9 Months Ended

Jun. 30, 2017

Partnership's Debt

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

	June 30,				September 30,
	2017				2016
	Carrying				Carrying
	Amount		Fair Value (a)		Amount		Fair Value (a)
Revolving Credit Facility Borrowings	$	—	$	—	$	—	$	—
Senior Secured Term Loan (b)	$	78,155	$	78,800	$	91,641	$	92,500
Total debt	$	78,155	$	78,800	$	91,641	$	92,500
Total short-term portion of debt	$	10,000	$	10,000	$	16,200	$	16,200
Total long-term portion of debt	$	68,155	$	68,800	$	75,441	$	76,300

(a) The face amount of the Partnership’s variable rate long-term debt approximates fair value.

(b) Carrying amounts are net of unamortized debt issuance costs of $0.6 million as of June 30, 2017, and $0.9 million as of September 30, 2016.

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Income Taxes (Tables)

9 Months Ended

Jun. 30, 2017

Current and Deferred Income Tax Expenses (Benefits)

The current and deferred income tax expenses (benefits) for the three and nine months ended June 30, 2017, and 2016, are as follows:

	Three Months Ended						Nine Months Ended
	June 30,						June 30,
(in thousands)	2017			2016			2017		2016
Income (loss) before income taxes	$	(21,766	)	$	(4,993	)	$	76,368	$	110,595
Current tax expense (benefit)		(5,764	)		(6,759	)		27,270		33,268
Deferred tax expense (benefit)		(2,670	)	$	5,004			4,451	$	13,298
Total tax expense (benefit)	$	(8,434	)	$	(1,755	)	$	31,721	$	46,566

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Supplemental Disclosure of Cash Flow Information (Tables)

9 Months Ended

Jun. 30, 2017

Supplemental Disclosure of Cash Flow Information

	Nine Months Ended
	June 30,
(in thousands)	2017		2016
Cash paid during the period for:
Income taxes, net	$	4,116	$	15,411
Interest	$	6,002	$	5,082
Non-cash operating activities:
Increase in interest expense—amortization of deferred charges on senior secured term loan	$	225	$	214

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Earnings Per Limited Partner Unit (Tables)

9 Months Ended

Jun. 30, 2017

Net Income Allocation and Per Unit Data

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

	Three Months Ended						Nine Months Ended
Basic and Diluted Earnings Per Limited Partner:	June 30,						June 30,
(in thousands, except per unit data)	2017			2016			2017		2016
Net income (loss)	$	(13,332	)	$	(3,238	)	$	44,647	$	64,029
Less General Partner’s interest in net income		(79	)		(19	)		259		362
Net income (loss) available to limited partners		(13,253	)		(3,219	)		44,388		63,667
Less dilutive impact of theoretical distribution of earnings under FASB ASC 260-10-45-60		—			—			5,420		9,313
Limited Partner’s interest in net income (loss) under FASB ASC 260-10-45-60	$	(13,253	)	$	(3,219	)	$	38,968	$	54,354
Per unit data:
Basic and diluted net income (loss) available to limited partners	$	(0.24	)	$	(0.06	)	$	0.79	$	1.11
Less dilutive impact of theoretical distribution of earnings under FASB ASC 260-10-45-60		—			—			0.09		0.16
Limited Partner’s interest in net income (loss) under FASB ASC 260-10-45-60	$	(0.24	)	$	(0.06	)	$	0.70	$	0.95
Weighted average number of Limited Partner units outstanding		55,888			57,188			55,888		57,237

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Partnership Organization - Additional Information (Detail) shares in Thousands		9 Months Ended
	Jul. 30, 2015 USD ($)	Jun. 30, 2017 Contract Customer shares	Sep. 30, 2016 shares
Limited Partners' Capital Account [Line Items]
Percentage of limited partner interest		99.40%
Percentage of general partner interest		0.60%
Common Stock
Limited Partners' Capital Account [Line Items]
Number of outstanding units | shares		55,888	55,888
Third Amendment
Limited Partners' Capital Account [Line Items]
Non Seasonal maximum borrowing capacity under revolving credit facility | $	$ 300,000,000
Maximum borrowing capacity (heating season December to April) under revolving credit facility | $	$ 450,000,000
Due date of debt	Jul. 30, 2020
Third Amendment | Term Loan
Limited Partners' Capital Account [Line Items]
Outstanding senior notes | $	$ 100,000,000
Senior secured term loan maturity period	5 years
Star Acquisitions, Inc
Limited Partners' Capital Account [Line Items]
Ownership interest of partnership		100.00%
Petro Holdings, Inc
Limited Partners' Capital Account [Line Items]
Ownership interest of Star Acquisitions Inc.		100.00%
Number of full-service residential and commercial home heating oil and propane customers served | Customer		441,000
Number of customers to whom only home heating oil, gasoline and diesel fuel were sold on a delivery only basis | Customer		73,000
Number of customers to whom ancillary services were provided | Customer		29,100
Number of service contracts for natural gas and other heating systems | Contract		14,900
Woodbury Insurance Co., Inc.
Limited Partners' Capital Account [Line Items]
Ownership interest of Star Acquisitions Inc.		100.00%
Petroleum Heat and Power Co., Inc.
Limited Partners' Capital Account [Line Items]
Ownership interest of partnership		100.00%
General Partner
Limited Partners' Capital Account [Line Items]
Number of outstanding units | shares		326	326

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Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($)	3 Months Ended	9 Months Ended
	Dec. 31, 2015	Jun. 30, 2017	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2015
Schedule Of Significant Accounting Policies [Line Items]
Cash, cash equivalents, and restricted cash		$ 94,824,000	$ 139,188,000	$ 171,156,000	$ 100,508,000
Cash and cash equivalents		94,574,000	139,188,000
Restricted cash		300,000
Accrued expenses and other current liabilities		130,776,000	103,855,000
Other long-term liabilities		25,082,000	25,255,000
Deferred charges and other assets, net		9,782,000	11,074,000
Long-term debt		$ 68,155,000	75,441,000
Operating lease expiration year		2032
Undiscounted future minimum lease payments through 2032		$ 131,800,000
New England Teamsters & Trucking Industry Pension Fund
Schedule Of Significant Accounting Policies [Line Items]
Accrued expenses and other current liabilities		200,000
Other long-term liabilities		17,400,000
Significant Other Observable Inputs Level 2 | New England Teamsters & Trucking Industry Pension Fund
Schedule Of Significant Accounting Policies [Line Items]
Multiemployer plan discounted withdrawal liability		22,200,000
Quoted Prices in Active Markets for Identical Assets Level 1
Schedule Of Significant Accounting Policies [Line Items]
Investments, debt securities		10,300,000
Investments, mutual funds		1,400,000
Accounting Standards Update 2015-03
Schedule Of Significant Accounting Policies [Line Items]
Deferred charges and other assets, net			11,100,000
Long-term debt			75,400,000
Accounting Standards Update 2015-03 | Scenario, Previously Reported
Schedule Of Significant Accounting Policies [Line Items]
Deferred charges and other assets, net			11,900,000
Long-term debt			$ 76,300,000
Subsidiaries of Swiss Re
Schedule Of Significant Accounting Policies [Line Items]
Derivative maximum payout		12,500,000
Subsidiaries of Swiss Re | Delivery and branch expenses
Schedule Of Significant Accounting Policies [Line Items]
Credit on weather hedge contract	$ 12,500,000	$ 0

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Common Unit Repurchase and Retirement - Additional Information (Detail) - USD ($) shares in Thousands	Jul. 30, 2015	Jun. 30, 2017	Jul. 31, 2013	Jul. 31, 2012
Capital Unit [Line Items]
Partnership's common units authorized for repurchase		7,344
Third Amendment
Capital Unit [Line Items]
Availability required to repurchase common units	$ 45,000,000
Percentage of the maximum facility size on a historical proforma and forward-looking basis	15.00%
Non Seasonal maximum borrowing capacity under revolving credit facility	$ 300,000,000
Minimum fixed charge coverage ratio for distributions to unit holders or to repurchase common units	115.00%
Initial Common Units Authorized Plan III Common Units Repurchase Program
Capital Unit [Line Items]
Partnership's common units authorized for repurchase				3,000
Additional Common Units Authorized Plan III Common Units Repurchase Program
Capital Unit [Line Items]
Partnership's common units authorized for repurchase			1,900

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Partnership's Repurchase Activities (Detail) - $ / shares shares in Thousands		60 Months Ended
		Sep. 30, 2016		Jun. 30, 2017
Capital Unit [Line Items]
Partnership's common units authorized for repurchase				7,344
Private Transaction
Capital Unit [Line Items]
Partnership's common units authorized for repurchase				2,450
Total Number of Units Purchased		2,450
Plan III Common Units Repurchase Program
Capital Unit [Line Items]
Partnership's common units authorized for repurchase				4,894
Total Number of Units Purchased	[1],[2]	5,137
Average Price Paid per Unit	[1],[3]	$ 5.78
Maximum Number of Units that May Yet Be Purchased		2,207	[1]	2,207

[1] Includes 2.45 million common units acquired in a private transaction.

[2] Units were repurchased as part of a publicly announced program, except as noted in a private transaction.

[3] Amounts include repurchase costs.

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Partnership's Repurchase Activities (Parenthetical) (Detail) shares in Thousands	60 Months Ended
	Sep. 30, 2016 shares
Private Transaction
Capital Unit [Line Items]
Total Number of Units Purchased	2,450

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Derivatives and Hedging-Disclosures and Fair Value Measurements - Additional Information (Detail) gal in Millions, $ in Millions	9 Months Ended
	Jun. 30, 2017 USD ($) gal	Jun. 30, 2016 gal	Sep. 30, 2016 USD ($)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Hedging positions secured under credit facility | $	$ 4.9		$ 0.3
Prepaid expenses and other current assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Aggregated cash posted as collateral in normal course of business | $	$ 0.5
Call Option
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	3.6	4.5
Put Option
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	5.0	4.1
Synthetic calls | Call Option
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	55.0	60.0
Inventory
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	9.0	6.6
Swap Contracts | Long
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	1.3	1.1
Future Contracts | Long
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	53.3	54.0
Future Contracts | Short
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	67.7	70.1
Spread Contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	0.4	0.7
Hedge its Internal Fuel Usage and Other Related Activities Swap Contracts Bought
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative activity volume	6.5	5.9

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Partnership's Financial Assets and Liabilities Measured at Fair Value on Recurring Basis (Detail) - Fair Value, Measurements, Recurring - Derivatives Not Designated as Hedging Instruments under FASB ASC 815-10 - Commodity Contract - USD ($) $ in Thousands	Jun. 30, 2017	Sep. 30, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts	$ 9,474	$ 13,061
Derivative Liabilities, commodity contracts	(14,370)	(10,555)
Fair asset and fair liability value of derivative instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts	8,378	11,692
Other long-term liabilities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts		1,369
Derivative Liabilities, commodity contracts		(565)
Fair liability and fair asset value of derivative instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, commodity contracts	(13,138)	(9,990)
Deferred charges and other assets, net and other long-term liabilities balances
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts	1,096
Derivative Liabilities, commodity contracts	(1,232)
Quoted Prices in Active Markets for Identical Assets Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts		481
Derivative Liabilities, commodity contracts		(2,087)
Quoted Prices in Active Markets for Identical Assets Level 1 | Other long-term liabilities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts		481
Derivative Liabilities, commodity contracts		(484)
Quoted Prices in Active Markets for Identical Assets Level 1 | Fair liability and fair asset value of derivative instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, commodity contracts		(1,603)
Significant Other Observable Inputs Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts	9,474	12,580
Derivative Liabilities, commodity contracts	(14,370)	(8,468)
Significant Other Observable Inputs Level 2 | Fair asset and fair liability value of derivative instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts	8,378	11,692
Significant Other Observable Inputs Level 2 | Other long-term liabilities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts		888
Derivative Liabilities, commodity contracts		(81)
Significant Other Observable Inputs Level 2 | Fair liability and fair asset value of derivative instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities, commodity contracts	(13,138)	$ (8,387)
Significant Other Observable Inputs Level 2 | Deferred charges and other assets, net and other long-term liabilities balances
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets, commodity contracts	1,096
Derivative Liabilities, commodity contracts	$ (1,232)

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Offsetting of Financial Assets (Liabilities) and Derivative Assets (Liabilities) (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Sep. 30, 2016
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]
Net Assets (Liabilities) Presented in the Statement of Financial Position		$ 3,987
Net Assets (Liabilities) Presented in the Statement of Financial Position	$ (4,760)	(2,285)
Subject to an enforceable master netting arrangement
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]
Gross Assets Recognized	9,474	13,061
Gross Liabilities Offset in the Statement of Financial Position	(14,370)	(10,555)
Net Assets (Liabilities) Presented in the Statement of Financial Position	(4,896)	2,506
Financial Instruments	0	0
Cash Collateral Received	0	0
Net Amount	(4,896)	2,506
Subject to an enforceable master netting arrangement | Fair liability and fair asset value of derivative instruments
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]
Gross Assets Recognized	8,378	3,976
Gross Liabilities Offset in the Statement of Financial Position	(13,138)	(6,261)
Net Assets (Liabilities) Presented in the Statement of Financial Position	(4,760)	(2,285)
Financial Instruments	0	0
Cash Collateral Received	0	0
Net Amount	(4,760)	(2,285)
Subject to an enforceable master netting arrangement | Other long-term liabilities
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]
Gross Assets Recognized	922	481
Gross Liabilities Offset in the Statement of Financial Position	(1,067)	(484)
Net Assets (Liabilities) Presented in the Statement of Financial Position	(145)	(3)
Financial Instruments	0	0
Cash Collateral Received	0	0
Net Amount	(145)	(3)
Subject to an enforceable master netting arrangement | Fair asset and fair liability value of derivative instruments
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]
Gross Assets Recognized		7,716
Gross Liabilities Offset in the Statement of Financial Position		(3,729)
Net Assets (Liabilities) Presented in the Statement of Financial Position		3,987
Financial Instruments	0	0
Cash Collateral Received	0	0
Net Amount		3,987
Subject to an enforceable master netting arrangement | Deferred charges and other assets, net
Fair Values Of Financial Assets And Liabilities Including Derivative Financial Instruments [Line Items]
Gross Assets Recognized	174	888
Gross Liabilities Offset in the Statement of Financial Position	(165)	(81)
Net Assets (Liabilities) Presented in the Statement of Financial Position	9	807
Financial Instruments	0	0
Cash Collateral Received	0	0
Net Amount	$ 9	$ 807

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Effect of Derivative Instruments on Statement of Operations (Detail) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (Gain) or Loss Unrealized, commodity contracts	[1]	$ 3,135	$ (11,283)	$ 7,026	$ (20,071)
Fair Value, Measurements, Recurring | Derivatives Not Designated as Hedging Instruments under FASB ASC 815-10 | Commodity Contract | Cost of product
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (Gain) or Loss Recognized, commodity contracts	[2]	1,092	8,177	4,073	16,978
Fair Value, Measurements, Recurring | Derivatives Not Designated as Hedging Instruments under FASB ASC 815-10 | Commodity Contract | Cost of installations and service
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (Gain) or Loss Recognized, commodity contracts	[2]		72	(526)	848
Fair Value, Measurements, Recurring | Derivatives Not Designated as Hedging Instruments under FASB ASC 815-10 | Commodity Contract | Delivery and branch expenses
Derivative Instruments, Gain (Loss) [Line Items]
Amount of (Gain) or Loss Recognized, commodity contracts	[2]	$ 27	$ 150	$ (422)	$ 1,029

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

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

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Components of Inventory (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Sep. 30, 2016
Inventory [Line Items]
Product	$ 21,364	$ 25,419
Parts and equipment	21,058	20,475
Total inventory	$ 42,422	$ 45,894

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Component of Property and Equipment (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Sep. 30, 2016
Property, Plant and Equipment [Line Items]
Property and equipment	$ 195,181	$ 184,079
Less: accumulated depreciation	120,690	113,669
Property and equipment, net	$ 74,491	$ 70,410

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Business Combinations - Additional Information (Detail) $ in Thousands	9 Months Ended
	Jun. 30, 2017 USD ($) PartnershipUnit	Sep. 30, 2016 USD ($)
Business Acquisition [Line Items]
Goodwill	$ 215,262	$ 212,760
Number of heating oil dealer acquired | PartnershipUnit	3
Heating Oil Dealer, Propane Dealer and Plumbing Service Provider
Business Acquisition [Line Items]
Aggregate purchase prices partnership acquired	$ 16,000
Cash paid	14,500
Deferred liabilities	1,500
Contingent consideration	600
Aggregate purchase price allocation, intangible assets	9,300
Goodwill	2,500
Aggregate purchase price allocation, fixed assets	5,000
Gross purchase price reduced by working capital credits	$ (800)

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Summary of Changes in the Partnership's Goodwill (Detail) $ in Thousands	9 Months Ended
	Jun. 30, 2017 USD ($)
Goodwill [Line Items]
Balance on beginning	$ 212,760
Fiscal year business combinations	2,502
Balance on ending	$ 215,262

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Intangible Assets Subject to Amortization (Detail) - USD ($) $ in Thousands	Jun. 30, 2017	Sep. 30, 2016
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 363,815	$ 354,522
Accum. Amortization	269,295	256,866
Net	94,520	97,656
Customer Lists
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	334,605	327,388
Accum. Amortization	261,017	250,427
Net	73,588	76,961
Trade Names And Other Intangibles
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	29,210	27,134
Accum. Amortization	8,278	6,439
Net	$ 20,932	$ 20,695

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Goodwill and Intangibles, net - Additional Information (Detail) - USD ($) $ in Millions	9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Finite-Lived Intangible Assets [Line Items]
Amortization expense for intangible assets	$ 12.4	$ 11.5

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Partnership's Debt (Detail) - USD ($) $ in Thousands		Jun. 30, 2017	Sep. 30, 2016
Debt Instrument [Line Items]
Long-term debt, carrying Amount		$ 78,155	$ 91,641
Current maturities of long-term debt, carrying Amount		10,000	16,200
Long-term portion of debt, Carrying Amount		68,155	75,441
Long-term debt, fair value	[1]	78,800	92,500
Current maturities of long-term debt, fair value	[1]	10,000	16,200
Long-term portion of debt, fair value	[1]	68,800	76,300
Term Loan
Debt Instrument [Line Items]
Long-term debt, carrying Amount	[2]	78,155	91,641
Long-term debt, fair value	[1],[2]	$ 78,800	$ 92,500

[1] The face amount of the Partnership's variable rate long-term debt approximates fair value.

[2] Carrying amounts are net of unamortized debt issuance costs of $0.6 million as of June 30, 2017, and $0.9 million as of September 30, 2016.

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Partnership's Debt (Parenthetical) (Detail) - USD ($) $ in Millions	Jun. 30, 2017	Sep. 30, 2016
Term Loan
Debt Instrument [Line Items]
Unamortized debt issuance costs	$ 0.6	$ 0.9

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Long-Term Debt and Bank Facility Borrowings - Additional Information (Detail) - USD ($)		Jul. 30, 2015	Jun. 30, 2017	Sep. 30, 2016
Debt Instrument [Line Items]
Hedging positions secured under credit facility			$ 4,900,000	$ 300,000
Letters of credit issued and outstanding			48,200,000	50,600,000
Long-term debt, fair value	[1]		78,800,000	92,500,000
Availability in compliance with the fixed charge coverage ratio			$ 160,300,000	163,400,000
Third Amendment
Debt Instrument [Line Items]
Non Seasonal maximum borrowing capacity under revolving credit facility		$ 300,000,000
Maximum borrowing capacity (heating season December to April) under revolving credit facility		450,000,000
Issuance of line of credit for working capital purposes		$ 100,000,000
Revolving credit facility expiry		Jul. 30, 2020
Additional revolving credit		$ 100,000,000
Facility size that can be increased without consulting bank group		$ 100,000,000
Term loan annual payment percentage		25.00%
Debt instrument, effective interest rate			4.01%
Minimum fixed charge coverage ratio		110.00%
Availability percentage to maximum facility size		12.50%
Third Amendment | Quarterly
Debt Instrument [Line Items]
Term loan periodic payment		$ 2,500,000
Third Amendment | Annually | Maximum
Debt Instrument [Line Items]
Term loan periodic payment		$ 15,000,000
Third Amendment | December through April
Debt Instrument [Line Items]
Commitment fee on the unused portion of the facility		0.30%
Third Amendment | May through November
Debt Instrument [Line Items]
Commitment fee on the unused portion of the facility		0.20%
Third Amendment | Quarters ending June or September | Maximum
Debt Instrument [Line Items]
Senior secured leverage ratio		300.00%
Third Amendment | Quarters ending December or March | Maximum
Debt Instrument [Line Items]
Senior secured leverage ratio		450.00%
Term Loan
Debt Instrument [Line Items]
Long-term debt, fair value	[1],[2]		$ 78,800,000	92,500,000
Term Loan | Third Amendment
Debt Instrument [Line Items]
Outstanding senior notes		$ 100,000,000
Senior secured term loan maturity period		5 years
Revolving Credit Facility
Debt Instrument [Line Items]
Revolving credit facility outstanding			$ 0	$ 0

[1] The face amount of the Partnership's variable rate long-term debt approximates fair value.

[2] Carrying amounts are net of unamortized debt issuance costs of $0.6 million as of June 30, 2017, and $0.9 million as of September 30, 2016.

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Current and Deferred Income Tax Expenses (Benefits) (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Deferred Income Tax Assets And Liabilities
Income (loss) before income taxes	$ (21,766)	$ (4,993)	$ 76,368	$ 110,595
Current tax expense (benefit)	(5,764)	(6,759)	27,270	33,268
Deferred tax expense (benefit)	(2,670)	5,004	4,451	13,298
Total tax expense (benefit)	$ (8,434)	$ (1,755)	$ 31,721	$ 46,566

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Income Taxes - Additional Information (Detail) - USD ($)		9 Months Ended
	Jan. 01, 2017	Jun. 30, 2017
Income Tax Disclosure [Abstract]
Net operating loss carryforward	$ 1,600,000
Unrecognized income tax benefits		$ 0
Federal
Income Tax Disclosure [Abstract]
Number of years for examination		4 years
New York
Income Tax Disclosure [Abstract]
Number of years for examination		4 years
Connecticut
Income Tax Disclosure [Abstract]
Number of years for examination		4 years
Pennsylvania
Income Tax Disclosure [Abstract]
Number of years for examination		4 years
New Jersey
Income Tax Disclosure [Abstract]
Number of years for examination		5 years
Minimum
Income Tax Disclosure [Abstract]
Annual limitation of federal NOLs	$ 1,000,000
Expiration date of net operating loss carryforward	Dec. 31, 2018
Maximum
Income Tax Disclosure [Abstract]
Annual limitation of federal NOLs	$ 2,200,000
Expiration date of net operating loss carryforward	Dec. 31, 2024

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Supplemental Disclosure of Cash Flow Information (Detail) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Cash paid during the period for:
Income taxes, net	$ 4,116	$ 15,411
Interest	6,002	5,082
Non-cash operating activities:
Increase in interest expense-amortization of deferred charges on senior secured term loan	$ 225	$ 214

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Net Income Allocation and Per Unit Data (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands		3 Months Ended		9 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Basic and Diluted Earnings Per Limited Partner:
Net income (loss)		$ (13,332)	$ (3,238)	$ 44,647	$ 64,029
Less General Partner's interest in net income		(79)	(19)	259	362
Net income (loss) available to limited partners		(13,253)	(3,219)	44,388	63,667
Less dilutive impact of theoretical distribution of earnings under FASB ASC 260-10-45-60				5,420	9,313
Limited Partner's interest in net income (loss) under FASB ASC 260-10-45-60		$ (13,253)	$ (3,219)	$ 38,968	$ 54,354
Per unit data:
Basic and diluted net income (loss) available to limited partners		$ (0.24)	$ (0.06)	$ 0.79	$ 1.11
Less dilutive impact of theoretical distribution of earnings under FASB ASC 260-10-45-60				0.09	0.16
Limited Partner's interest in net income (loss) under FASB ASC 260-10-45-60	[1]	$ (0.24)	$ (0.06)	$ 0.70	$ 0.95
Weighted average number of Limited Partner units outstanding		55,888	57,188	55,888	57,237

[1] See Note 13 Earnings Per Limited Partner Unit.

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Subsequent Events - Additional Information (Detail) - Subsequent Event - Dividend Declared $ / shares in Units, $ in Millions	1 Months Ended
	Jul. 31, 2017 USD ($) $ / shares
Subsequent Event [Line Items]
Distribution declared | $ / shares	$ 0.11
Partners capital projected distribution amount on annualized basis | $ / shares	0.44
Minimum dividend distribution per unit | $ / shares	$ 0.0675
Percentage of distributions to common unit holders in excess of minimum quarterly distribution	90.00%
Percentage of distributions to general unit holders in excess of minimum quarterly distribution	10.00%
Amount to paid to common unit holders	$ 6.1
Amount to paid to the General Partner	0.2
Incentive distribution to the General Partner	0.1
Incentive distributions to management	$ 0.1
Dividend payable date	Aug. 08, 2017
Dividend record date	Jul. 31, 2017