10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C.  20549

FORM 10-Q

☒ Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended June 30, 2018

☐ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission File Number:  1-14222

SUBURBAN PROPANE PARTNERS, L.P.

(Exact name of registrant as specified in its charter)

Delaware	22-3410353
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)

240 Route 10 West

Whippany, NJ 07981

(973)  887-5300

(Address, including zip code, and telephone number,

including area code, of registrant’s principal executive offices)

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 (§232.405 of this chapter) 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, an accelerated filer, a non-accelerated filer, a 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	☐	(do not check if a smaller reporting company)	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 Exchange Act).    Yes  ☐    No  ☒

At August 6, 2018, there were 61,405,409 Common Units of Suburban Propane Partners, L.P. outstanding.

SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

INDEX TO FORM 10-Q

		Page
	PART I. FINANCIAL INFORMATION	1
ITEM 1.	FINANCIAL STATEMENTS (UNAUDITED)	1
	Condensed Consolidated Balance Sheets as of June 30, 2018 and September 30, 2017	1
	Condensed Consolidated Statements of Operations for the three months ended June 30, 2018 and June 24, 2017	2
	Condensed Consolidated Statements of Operations for the nine months ended June 30, 2018 and June 24, 2017	3
	Condensed Consolidated Statements of Comprehensive Income for the three and nine months ended June 30, 2018 and June 24, 2017	4
	Condensed Consolidated Statements of Cash Flows for the nine months ended June 30, 2018 and June 24, 2017	5
	Condensed Consolidated Statement of Partners’ Capital for the nine months ended June 30, 2018	6
	Notes to Condensed Consolidated Financial Statements	7
ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	22
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	31
ITEM 4.	CONTROLS AND PROCEDURES	33
	PART II. OTHER INFORMATION	34
ITEM 1.	LEGAL PROCEEDINGS	34
ITEM 1A.	RISK FACTORS	34
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	34
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	34
ITEM 4.	MINE SAFETY DISCLOSURES	34
ITEM 5.	OTHER INFORMATION	34
ITEM 6.	EXHIBITS	35
SignaturEs		36

DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains forward-looking statements (“Forward-Looking Statements”) as defined in the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended, relating to future business expectations and predictions and financial condition and results of operations of Suburban Propane Partners, L.P. (the “Partnership”). Some of these statements can be identified by the use of forward-looking terminology such as “prospects,” “outlook,” “believes,” “estimates,” “intends,” “may,” “will,” “should,” “could,” “anticipates,” “expects” or “plans” or the negative or other variation of these or similar words, or by discussion of trends and conditions, strategies or risks and uncertainties.  These Forward-Looking Statements involve certain risks and uncertainties that could cause actual results to differ materially from those discussed or implied in such Forward-Looking Statements (statements contained in this Quarterly Report identifying such risks and uncertainties are referred to as “Cautionary Statements”). The risks and uncertainties and their impact on the Partnership’s results include, but are not limited to, the following risks:

• The impact of weather conditions on the demand for propane, fuel oil and other refined fuels, natural gas and electricity;

• Volatility in the unit cost of propane, fuel oil and other refined fuels, natural gas and electricity, the impact of the Partnership’s hedging and risk management activities, and the adverse impact of price increases on volumes sold as a result of customer conservation;

• The ability of the Partnership to compete with other suppliers of propane, fuel oil and other energy sources;

• The impact on the price and supply of propane, fuel oil and other refined fuels from the political, military or economic instability of the oil producing nations, global terrorism and other general economic conditions;

• The ability of the Partnership to acquire sufficient volumes of, and the costs to the Partnership of acquiring, transporting and storing, propane, fuel oil and other refined fuels;

• The ability of the Partnership to acquire and maintain reliable transportation for its propane, fuel oil and other refined fuels;

• The ability of the Partnership to retain customers or acquire new customers;

• The impact of customer conservation, energy efficiency and technology advances on the demand for propane, fuel oil and other refined fuels, natural gas and electricity;

• The ability of management to continue to control expenses;

• The impact of changes in applicable statutes and government regulations, or their interpretations, including those relating to the environment and climate change, derivative instruments and other regulatory developments on the Partnership’s business;

• The impact of changes in tax laws that could adversely affect the tax treatment of the Partnership for income tax purposes;

• The impact of legal proceedings on the Partnership’s business;

• The impact of operating hazards that could adversely affect the Partnership’s operating results to the extent not covered by insurance;

• The Partnership’s ability to make strategic acquisitions and successfully integrate them;

• The impact of current conditions in the global capital and credit markets, and general economic pressures;

• The operating, legal and regulatory risks the Partnership may face; and

• Other risks referenced from time to time in filings with the Securities and Exchange Commission (“SEC”) and those factors listed or incorporated by reference into the Partnership’s most recent Annual Report under “Risk Factors.”

Some of these Forward-Looking Statements are discussed in more detail in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this Quarterly Report.  Reference is also made to the risk factors discussed in Item 1A of our Annual Report on Form 10-K for the fiscal year ended September 30, 2017.  On different occasions, the Partnership or its representatives have made or may make Forward-Looking Statements in other filings with the SEC, press releases or oral statements made by or with the approval of one of the Partnership’s authorized executive officers.  Readers are cautioned not to place undue reliance on Forward-Looking Statements, which reflect management’s view only as of the date made.  The Partnership undertakes no obligation to update any Forward-Looking Statement or Cautionary Statement, except as required by law.  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 in this Quarterly Report and in future SEC reports.

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)

(unaudited)

	June 30,			September 30,
	2018			2017
ASSETS
Current assets:
Cash and cash equivalents	$	3,439		$	2,789
Accounts receivable, less allowance for doubtful accounts of $4,643 and    $3,044, respectively		88,047			65,683
Inventories		49,838			53,220
Other current assets		22,435			17,801
Total current assets		163,759			139,493
Property, plant and equipment, net		659,581			692,627
Goodwill		1,093,470			1,094,635
Other intangible assets, net		189,382			219,876
Other assets		25,341			24,652
Total assets	$	2,131,533		$	2,171,283
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable	$	31,098		$	38,652
Accrued employment and benefit costs		28,756			27,402
Customer deposits and advances		45,487			97,023
Accrued interest		14,550			13,682
Other current liabilities		33,782			33,607
Total current liabilities		153,673			210,366
Long-term borrowings		1,262,178			1,272,164
Accrued insurance		57,576			54,921
Other liabilities		79,819			80,850
Total liabilities		1,553,246			1,618,301
Commitments and contingencies
Partners’ capital:
Common Unitholders (61,405 and 61,105 units issued and outstanding at    June 30, 2018 and September 30, 2017, respectively)		604,828			581,794
Accumulated other comprehensive loss		(26,541	)		(28,812	)
Total partners’ capital		578,287			552,982
Total liabilities and partners’ capital	$	2,131,533		$	2,171,283

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per unit amounts)

(unaudited)

	Three Months Ended
	June 30,			June 24,
	2018			2017
Revenues
Propane	$	205,400		$	188,406
Fuel oil and refined fuels		15,400			12,886
Natural gas and electricity		10,403			11,923
All other		10,733			9,680
		241,936			222,895
Costs and expenses
Cost of products sold		95,392			92,094
Operating		97,519			97,070
General and administrative		14,705			12,968
Depreciation and amortization		31,259			31,825
		238,875			233,957
Operating income (loss)		3,061			(11,062	)
Interest expense, net		19,512			18,502
Loss before provision for income taxes		(16,451	)		(29,564	)
Provision for income taxes		144			152
Net loss	$	(16,595	)	$	(29,716	)
Net loss per Common Unit - basic	$	(0.27	)	$	(0.48	)
Weighted average number of Common Units outstanding - basic		61,598			61,290
Net loss per Common Unit - diluted	$	(0.27	)	$	(0.48	)
Weighted average number of Common Units outstanding - diluted		61,598			61,290

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per unit amounts)

(unaudited)

	Nine Months Ended
	June 30,			June 24,
	2018			2017
Revenues
Propane	$	990,344		$	843,519
Fuel oil and refined fuels		82,414			69,612
Natural gas and electricity		43,942			44,229
All other		34,795			33,420
		1,151,495			990,780
Costs and expenses
Cost of products sold		507,223			402,726
Operating		310,132			306,839
General and administrative		49,685			40,179
Depreciation and amortization		94,593			95,756
		961,633			845,500
Loss on sale of business		4,823			—
Operating income		185,039			145,280
Loss on debt extinguishment		—			1,567
Interest expense, net		58,428			54,820
Income before (benefit from) provision for income taxes		126,611			88,893
(Benefit from) provision for income taxes		(749	)		308
Net income	$	127,360		$	88,585
Net income per Common Unit - basic	$	2.07		$	1.45
Weighted average number of Common Units outstanding - basic		61,542			61,227
Net income per Common Unit - diluted	$	2.06		$	1.44
Weighted average number of Common Units outstanding - diluted		61,780			61,410

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(in thousands)

(unaudited)

	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,		June 24,
	2018			2017			2018		2017
Net (loss) income	$	(16,595	)	$	(29,716	)	$	127,360	$	88,585
Other comprehensive income:
Net unrealized (losses) on cash flow hedges		—			—			—		(10	)
Reclassification of realized losses on cash flow hedges    into earnings		—			—			—		215
Amortization of net actuarial losses and prior service    credits into earnings		757			1,203			2,271		3,609
Other comprehensive income		757			1,203			2,271		3,814
Total comprehensive (loss) income	$	(15,838	)	$	(28,513	)	$	129,631	$	92,399

The accompanying notes are an integral part of these condensed consolidated financial statements.

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

(unaudited)

	Nine Months Ended
	June 30,			June 24,
	2018			2017
Cash flows from operating activities:
Net income	$	127,360		$	88,585
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization		94,593			95,756
Loss on sale of business		4,823			—
Loss on debt extinguishment		—			1,567
Other, net		7,065			7,271
Changes in assets and liabilities:
Accounts receivable		(21,932	)		(19,143	)
Inventories		3,545			3,492
Other current and noncurrent assets		(5,111	)		(5,193	)
Accounts payable		(6,434	)		(2,826	)
Accrued employment and benefit costs		1,355			6,925
Customer deposits and advances		(51,536	)		(49,652	)
Contributions to defined benefit pension plan		(3,839	)		(7,542	)
Other current and noncurrent liabilities		6,227			4,738
Net cash provided by operating activities		156,116			123,978
Cash flows from investing activities:
Capital expenditures		(25,847	)		(22,004	)
Acquisition of businesses		(14,873	)		—
Proceeds from sale of business		2,800			—
Proceeds from sale of property, plant and equipment		5,143			3,829
Net cash (used in) investing activities		(32,777	)		(18,175	)
Cash flows from financing activities:
Proceeds from long-term borrowings		—			350,000
Repayments of long-term borrowings (includes premium and fees)		—			(360,931	)
Proceeds from borrowings under revolving credit facility		283,700			273,240
Repayments of borrowings under revolving credit facility		(295,200	)		(232,095	)
Issuance costs associated with long-term borrowings		—			(7,064	)
Partnership distributions		(110,342	)		(162,347	)
Other, net		(847	)		(736	)
Net cash (used in) financing activities		(122,689	)		(139,933	)
Net increase (decrease) in cash and cash equivalents		650			(34,130	)
Cash and cash equivalents at beginning of period		2,789			37,341
Cash and cash equivalents at end of period	$	3,439		$	3,211

The accompanying notes are an integral part of these condensed consolidated financial statements.

5

SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL

(in thousands)

(unaudited)

						Accumulated
						Other			Total
	Number of		Common			Comprehensive			Partners’
	CommonUnits		Unitholders			(Loss)			Capital
Balance at September 30, 2017		61,105	$	581,794		$	(28,812	)	$	552,982
Net income				127,360						127,360
Other comprehensive income							2,271			2,271
Partnership distributions				(110,342	)					(110,342	)
Common Units issued under Restricted Unit Plans		300
Compensation cost recognized under Restricted Unit Plans, net of    forfeitures				6,016						6,016
Balance at June 30, 2018		61,405	$	604,828		$	(26,541	)	$	578,287

The accompanying notes are an integral part of these condensed consolidated financial statements.

6

SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(dollars in thousands, except unit and per unit amounts)

(unaudited)

1. Partnership Organization and Formation

Suburban Propane Partners, L.P. (the “Partnership”) is a publicly traded Delaware limited partnership principally engaged, through its operating partnership and subsidiaries, in the retail marketing and distribution of propane, fuel oil and refined fuels, as well as the marketing of natural gas and electricity in deregulated markets.  In addition, to complement its core marketing and distribution businesses, the Partnership services a wide variety of home comfort equipment, particularly for heating and ventilation.  The publicly traded limited partner interests in the Partnership are evidenced by common units traded on the New York Stock Exchange (“Common Units”), with 61,405,409 Common Units outstanding at June 30, 2018.  The holders of Common Units are entitled to participate in distributions and exercise the rights and privileges available to limited partners under the Third Amended and Restated Agreement of Limited Partnership (the “Partnership Agreement”), as amended.  Rights and privileges under the Partnership Agreement include, among other things, the election of all members of the Board of Supervisors and voting on the removal of the general partner.

Suburban Propane, L.P. (the “Operating Partnership”), a Delaware limited partnership, is the Partnership’s operating subsidiary formed to operate the propane business and assets.  In addition, Suburban Sales & Service, Inc. (the “Service Company”), a subsidiary of the Operating Partnership, was formed to operate the service work and appliance and parts businesses of the Partnership.  The Operating Partnership, together with its direct and indirect subsidiaries, accounts for substantially all of the Partnership’s assets, revenues and earnings.  The Partnership, the Operating Partnership and the Service Company commenced operations in March 1996 in connection with the Partnership’s initial public offering.

The general partner of both the Partnership and the Operating Partnership is Suburban Energy Services Group LLC (the “General Partner”), a Delaware limited liability company, the sole member of which is the Partnership’s Chief Executive Officer.  Other than as a holder of 784 Common Units that will remain in the General Partner, the General Partner does not have any economic interest in the Partnership or the Operating Partnership.

The Partnership’s fuel oil and refined fuels, natural gas and electricity and services businesses are structured as either limited liability companies that are treated as corporations or corporate entities (collectively referred to as the “Corporate Entities”) and, as such, are subject to corporate level U.S. income tax.

Suburban Energy Finance Corp., a direct 100%-owned subsidiary of the Partnership, was formed on November 26, 2003 to serve as co-issuer, jointly and severally with the Partnership, of the Partnership’s senior notes.

2. Basis of Presentation

Principles of Consolidation.  The condensed consolidated financial statements include the accounts of the Partnership, the Operating Partnership and all of its direct and indirect subsidiaries.  All significant intercompany transactions and account balances have been eliminated.  The Partnership consolidates the results of operations, financial condition and cash flows of the Operating Partnership as a result of the Partnership’s 100% limited partner interest in the Operating Partnership.

The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”).  They include all adjustments that the Partnership considers necessary for a fair statement of the results of operations, financial position and cash flows for the interim periods presented.  Such adjustments consist only of normal recurring items, unless otherwise disclosed.  These financial statements should be read in conjunction with the financial statements included in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 30, 2017.  Due to the seasonal nature of the Partnership’s operations, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.

Fiscal Period.  The Partnership uses a 52/53 week fiscal year which ends on the last Saturday in September.  The Partnership’s fiscal quarters are generally thirteen weeks in duration.  When the Partnership’s fiscal year is 53 weeks long, as was the case for fiscal 2017, the corresponding fourth quarter is fourteen weeks in duration.

7

Revenue Recognition.  Sales of propane, fuel oil and refined fuels are recognized at the time product is delivered to the customer.  Revenue from the sale of appliances and equipment is recognized at the time of sale or when installation is complete, as applicable.  Revenue from repairs, maintenance and other service activities is recognized upon completion of the service.  Revenue from annually billed service contracts is recognized ratably over the service period.  Revenue from the natural gas and electricity business is recognized based on customer usage as determined by meter readings for amounts delivered, some of which may be unbilled at the end of each accounting period.  Revenue from annually billed tank fees is deferred at the time of billings and recognized on a straight-line basis over one year.

Fair Value Measurements.  The Partnership measures certain of its assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants – in either the principal market or the most advantageous market.  The principal market is the market with the greatest level of activity and volume for the asset or liability.

The common framework for measuring fair value utilizes a three-level hierarchy to prioritize the inputs used in the valuation techniques to derive fair values.  The basis for fair value measurements for each level within the hierarchy is described below with Level 1 having the highest priority and Level 3 having the lowest.

• Level 1: Quoted prices in active markets for identical assets or liabilities.

• Level 2: Quoted prices in active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations in which all significant inputs are observable in active markets.

• Level 3: Valuations derived from valuation techniques in which one or more significant inputs are unobservable.

Business Combinations.  The Partnership accounts for business combinations using the acquisition method and accordingly, the assets and liabilities of the acquired entities are recorded at their estimated fair values at the acquisition date.  Goodwill represents the excess of the purchase price over the fair value of the net assets acquired, including the amount assigned to identifiable intangible assets.  The primary drivers that generate goodwill are the value of synergies between the acquired entities and the Partnership, and the acquired assembled workforce, neither of which qualifies as an identifiable intangible asset.  Identifiable intangible assets with finite lives are amortized over their useful lives.  The results of operations of acquired businesses are included in the consolidated financial statements from the acquisition date.  The Partnership expenses all acquisition-related costs as incurred.

Use of Estimates.  The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“US GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.  Estimates have been made by management in the areas of self-insurance and litigation reserves, pension and other postretirement benefit liabilities and costs, valuation of derivative instruments, depreciation and amortization of long-lived assets, asset impairment assessments, tax valuation allowances, allowances for doubtful accounts, and purchase price allocation for acquired businesses.  The Partnership uses Society of Actuaries life expectancy information when developing the annual mortality assumptions for the pension and postretirement benefit plans, which are used to measure net periodic benefit costs and the obligation under these plans.  Actual results could differ from those estimates, making it reasonably possible that a material change in these estimates could occur in the near term.

Reclassifications.  Certain prior period amounts have been reclassified to conform with the current period presentation.  See Recently Adopted Accounting Pronouncements, below.

Recently Issued Accounting Pronouncements.  In March 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” (“ASU 2017-07”).  This update provides guidance on the capitalization, presentation and disclosure of net benefit costs.  ASU 2017-07 is effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019 and will be applied retrospectively upon adoption.  The Partnership is currently evaluating the impact that the standard will have on the Partnership’s consolidated statements of operations.

In January 2017, the FASB issued ASU 2017-04, “Simplifying the Test for Goodwill Impairment” (“ASU 2017-04”).  This update eliminates the second of the two-step goodwill impairment test, as described in Note 6, “Goodwill and Other Intangible Assets.”  Instead, an entity should perform its annual or interim goodwill impairment test by comparing the fair value of a reporting unit to its carrying amount and recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value, not to exceed the total amount of goodwill allocated to the reporting unit.  ASU 2017-04 is effective for the first interim period within annual reporting periods beginning after December 15, 2019, which will be the Partnership’s first quarter of fiscal 2021.  Early adoption of ASU 2017-04 is permitted.  The Partnership does not expect that the adoption of ASU 2017-04 will have a material impact on the Partnership’s consolidated financial statements.

In August 2016, the FASB issued ASU 2016-15, “Classification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”).  This update addresses eight specific cash flow issues and is intended to reduce diversity in practice on how certain cash receipts

8

and cash payments are presented and classified in the statement of cash flows.  ASU 2016-15 is effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019.  Early adoption of ASU 2016-15 is permitted.  The Partnership is currently evaluating the impact of adopting the standard on the Partnership’s consolidated statements of cash flows.

In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”). The standard amends the existing accounting standards for lease accounting, including requiring lessees to recognize most leases on their balance sheets and making targeted changes to lessor accounting. ASU 2016-02 is effective for the first interim period within annual reporting periods beginning after December 15, 2018, which will be the Partnership’s first quarter of fiscal 2020.  Early adoption of ASU 2016-02 is permitted. The new leases standard requires a modified retrospective transition approach for all leases existing at, or entered into after, the date of initial application, with an option to use certain transition relief. The Partnership is currently evaluating the impact of adopting ASU 2016-02 on the Partnership’s consolidated financial statements.

In May 2014, the FASB issued ASU 2014-09 “Revenue from Contracts with Customers” (“ASU 2014-09”).  This update provides a principles-based approach to revenue recognition, requiring revenue recognition to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  The ASU provides a five-step model to be applied to all contracts with customers. The five steps are to identify the contract(s) with the customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract and recognize revenue when each performance obligation is satisfied. On July 9, 2015, the FASB finalized a one-year deferral of the effective date of ASU 2014-09.  The revenue standard is therefore effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019.  Early adoption as of the original effective date is permitted.  ASU 2014-09 can be applied either retrospectively to each prior reporting period presented or with the cumulative effect of initially applying the update recognized at the date of the initial application along with additional disclosures.  While the Partnership is still in the process of evaluating the potential impact of ASU 2014-09, it does not expect its adoption will have a material impact on the Partnership’s consolidated financial statements.

Recently Adopted Accounting Pronouncements.During the first quarter of fiscal 2018, the Partnership adopted new accounting guidance regarding stock-based compensation under ASU 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”).  Cash payments made to the taxing authorities on employees’ behalf for withheld shares are now presented as financing activities on the condensed consolidated statement of cash flows, rather than operating activities.  The amounts paid to federal and state taxing authorities were $847 and $736 for the nine months ended June 30, 2018 and June 24, 2017, respectively.

3. Acquisition and Disposition of Businesses

On November 7, 2017, the Operating Partnership acquired the propane assets and operations of a propane retailer headquartered in California for $4,871, including $750 for non-compete consideration, plus working capital acquired. As of June 30, 2018, $4,251 was paid and the remainder of the purchase price will be funded in accordance with the terms of the asset purchase and non-compete agreements.  The acquisition was consummated pursuant to the Partnership’s strategic growth initiatives. The purchase price allocation and results of operations of the acquired business were not material to the Partnership’s condensed consolidated financial position and statement of operations.

On December 8, 2017, the Operating Partnership sold certain assets and operations in a non-strategic market of its propane segment for $2,800, plus working capital consideration, resulting in a loss of $4,823 that was recognized during the first quarter of fiscal 2018, principally for the allocated goodwill and other identifiable intangible assets associated with this business. The corresponding net assets and results of operations were not material to the Partnership’s condensed consolidated results of operations, financial position and cash flows.

On April 5, 2018, the Operating Partnership acquired the propane assets and operations of two affiliated propane retailers headquartered in Florida for $11,900, including $1,750 for non-compete consideration, plus working capital acquired. As of June 30, 2018, $10,622 was paid and the remainder of the purchase price will be funded in accordance with the terms of the asset purchase and non-compete agreements.  The acquisition was consummated pursuant to the Partnership’s strategic growth initiatives.  The preliminary purchase price allocation and results of operations of the acquired business were not material to the Partnership’s condensed consolidated financial position and statement of operations.

4. Financial Instruments and Risk Management

Cash and Cash Equivalents.  The Partnership considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents.  The carrying amount approximates fair value because of the short-term maturity of these instruments.

9

Derivative Instruments and Hedging Activities

Commodity Price Risk.  Given the retail nature of its operations, the Partnership maintains a certain level of priced physical inventory to help ensure its field operations have adequate supply commensurate with the time of year.  The Partnership’s strategy is to keep its physical inventory priced relatively close to market for its field operations.  The Partnership enters into a combination of exchange-traded futures and option contracts and, in certain instances, over-the-counter options and swap contracts (collectively, “derivative instruments”) to hedge price risk associated with propane and fuel oil physical inventories, as well as future purchases of propane or fuel oil used in its operations and to help ensure adequate supply during periods of high demand.  In addition, the Partnership sells propane and fuel oil to customers at fixed prices, and enters into derivative instruments to hedge a portion of its exposure to fluctuations in commodity prices as a result of selling the fixed price contracts.  Under this risk management strategy, realized gains or losses on derivative instruments will typically offset losses or gains on the physical inventory once the product is sold or delivered as it pertains to fixed price contracts.  All of the Partnership’s derivative instruments are reported on the condensed consolidated balance sheet at their fair values.  In addition, in the course of normal operations, the Partnership routinely enters into contracts such as forward priced physical contracts for the purchase or sale of propane and fuel oil that qualify for and are designated as normal purchase or normal sale contracts.  Such contracts are exempted from the fair value accounting requirements and are accounted for at the time product is purchased or sold under the related contract.  The Partnership does not use derivative instruments for speculative trading purposes.  Market risks associated with derivative instruments are monitored daily for compliance with the Partnership’s Hedging and Risk Management Policy which includes volume limits for open positions.  Priced on-hand inventory is also reviewed and managed daily as to exposures to changing market prices.

On the date that derivative instruments are entered into, other than those designated as normal purchases or normal sales, the Partnership makes a determination as to whether the derivative instrument qualifies for designation as a hedge.  Changes in the fair value of derivative instruments are recorded each period in current period earnings or other comprehensive income (“OCI”), depending on whether the derivative instrument is designated as a hedge and, if so, the type of hedge.  For derivative instruments designated as cash flow hedges, the Partnership formally assesses, both at the hedge contract’s inception and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows of hedged items.  Changes in the fair value of derivative instruments designated as cash flow hedges are reported in OCI to the extent effective and reclassified into earnings during the same period in which the hedged item affects earnings.  The mark-to-market gains or losses on ineffective portions of cash flow hedges are recognized in earnings immediately.  Changes in the fair value of derivative instruments that are not designated as cash flow hedges, and that do not meet the normal purchase and normal sale exemption, are recorded within earnings as they occur.  Cash flows associated with derivative instruments are reported as operating activities within the condensed consolidated statement of cash flows.

Interest Rate Risk.  A portion of the Partnership’s borrowings bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, LIBOR plus an applicable margin or the base rate, defined as the higher of the Federal Funds Rate plus ½ of 1% or the agent bank’s prime rate, or LIBOR plus 1%, plus the applicable margin.  The applicable margin is dependent on the level of the Partnership’s total leverage (the ratio of total debt to income before deducting interest expense, income taxes, depreciation and amortization (“EBITDA”)).  Therefore, the Partnership is subject to interest rate risk on the variable component of the interest rate.  From time to time, the Partnership manages part of its variable interest rate risk by entering into interest rate swap agreements. The interest rate swaps have been designated as, and are accounted for as, cash flow hedges.  The fair value of the interest rate swaps are determined using an income approach, whereby future settlements under the swaps are converted into a single present value, with fair value being based on the value of current market expectations about those future amounts.  Changes in the fair value are recognized in OCI until the hedged item is recognized in earnings.  However, due to changes in the underlying interest rate environment, the corresponding value in OCI is subject to change prior to its impact on earnings.

Valuation of Derivative Instruments.  The Partnership measures the fair value of its exchange-traded options and futures contracts using quoted market prices found on the New York Mercantile Exchange (the “NYMEX”) (Level 1 inputs); the fair value of its swap contracts using quoted forward prices, and the fair value of its interest rate swaps using model-derived valuations driven by observable projected movements of the 3-month LIBOR (Level 2 inputs); and the fair value of its over-the-counter options contracts using Level 3 inputs.  The Partnership’s over-the-counter options contracts are valued based on an internal option model.  The inputs utilized in the model are based on publicly available information as well as broker quotes.  The significant unobservable inputs used in the fair value measurements of the Partnership’s over-the-counter options contracts are interest rate and market volatility.

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The following summarizes the fair value of the Partnership’s derivative instruments and their location in the condensed consolidated balance sheets as of June 30, 2018 and September 30, 2017, respectively:

	As of June 30, 2018			As of September 30, 2017
Asset Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity-related derivatives	Other current assets	$	10,953	Other current assets	$	11,164
	Other assets		158	Other assets		771
		$	11,111		$	11,935
Liability Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity-related derivatives	Other current liabilities	$	4,962	Other current liabilities	$	1,978
	Other liabilities		—	Other liabilities		432
		$	4,962		$	2,410

The following summarizes the reconciliation of the beginning and ending balances of assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Nine Months Ended						Nine Months Ended
	June 30, 2018						June 24, 2017
	Assets			Liabilities			Assets			Liabilities
Beginning balance of over-the-counter options	$	4,108		$	737		$	809		$	—
Beginning balance realized during the period		(3,277	)		(737	)		(589	)		—
Contracts purchased during the period		1,352			158			—			—
Change in the fair value of outstanding contracts		(800	)		—			(115	)		—
Ending balance of over-the-counter options	$	1,383		$	158		$	105		$	—

As of June 30, 2018 and September 30, 2017, the Partnership’s outstanding commodity-related derivatives had a weighted average maturity of approximately four and five months, respectively.

The effect of the Partnership’s derivative instruments on the condensed consolidated statements of operations and the condensed consolidated statements of comprehensive income, as applicable, for the three and nine months ended June 30, 2018 and June 24, 2017 are as follows:

	Three Months Ended June 30, 2018					Three Months Ended June 24, 2017
Derivatives in Cash Flow	Gains (Losses) Recognized  in OCI		Gains (Losses) Reclassified from Accumulated OCI into Income			Gains (Losses) Recognized  in OCI		Gains (Losses) Reclassified from Accumulated OCI into Income
Hedging Relationships	(Effective Portion)		Location	Amount		(Effective Portion)		Location	Amount
Interest rate swap	$	—	Interest expense	$	—	$	—	Interest expense	$	—
Derivatives Not Designated as Hedging Instruments			Unrealized Gains (Losses) Recognized in Income					Unrealized Gains (Losses) Recognized in Income
			Location	Amount				Location	Amount
Commodity-related    derivatives			Cost of products sold	$	3,806			Cost of products sold	$	(655	)

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Nine Months Ended June 30, 2018

Nine Months Ended June 24, 2017

Derivatives in Cash Flow

Gains (Losses) Recognized  in OCI

Gains (Losses) Reclassified from Accumulated OCI into Income

Gains (Losses) Recognized  in OCI

Gains (Losses) Reclassified from Accumulated OCI into Income

Hedging Relationships

(Effective Portion)

Location

Amount

(Effective Portion)

Location

Amount

Interest rate swap

$

—

Interest expense

$

—

$

(10

)

Interest expense

$

(215

)

Derivatives Not Designated as Hedging Instruments

Unrealized Gains (Losses) Recognized in Income

Unrealized Gains (Losses) Recognized in Income

Location

Amount

Location

Amount

Commodity-related    derivatives

Cost of products sold

$

(1,421

)

Cost of products sold

$

(2,708

)

The following table presents the fair value of the Partnership’s recognized derivative assets and liabilities on a gross basis and amounts offset on the condensed consolidated balance sheets subject to enforceable master netting arrangements or similar agreements:

	As of June 30, 2018							As of September 30, 2017
						Net amounts							Net amounts
						presented in the							presented in the
	Gross amounts		Effects of netting			balance sheet		Gross amounts		Effects of netting			balance sheet
Asset Derivatives
Commodity-related derivatives	$	19,688	$	(8,577	)	$	11,111	$	16,378	$	(4,443	)	$	11,935
Liability Derivatives
Commodity-related derivatives	$	13,539	$	(8,577	)	$	4,962	$	6,853	$	(4,443	)	$	2,410

The Partnership had no cash collateral requirements as of June 30, 2018 and September 30, 2017 with its brokers for outstanding commodity-related derivatives.

Bank Debt and Senior Notes.  The fair value of the borrowings under the Revolving Credit Facility (defined below in Note 8) approximates the carrying value since the interest rates are adjusted quarterly to reflect market conditions. Based upon quoted market prices (a Level 1 input), the fair value of the Senior Notes (also defined below in Note 8) of the Partnership are as follows:

	As of
	June 30,		September 30,
	2018		2017
5.5% senior notes due June 1, 2024	$	511,875	$	527,888
5.75% senior notes due March 1, 2025		240,625		248,750
5.875% senior notes due March 1, 2027		327,250		349,125
	$	1,079,750	$	1,125,763

5. Inventories

Inventories are stated at the lower of cost or market. Cost is determined using a weighted average method for propane, fuel oil and refined fuels and natural gas, and a standard cost basis for appliances, which approximates average cost. Inventories consist of the following:

	As of
	June 30,		September 30,
	2018		2017
Propane, fuel oil and refined fuels and natural gas	$	48,210	$	51,844
Appliances		1,628		1,376
	$	49,838	$	53,220

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6. Goodwill and Other Intangible Assets

Goodwill represents the excess of the purchase price over the fair value of net assets acquired. Goodwill is subject to an impairment review at a reporting unit level, on an annual basis as of the end of fiscal July of each year, or when an event occurs or circumstances change that would indicate potential impairment.

The Partnership has the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, then performing the two-step impairment test is unnecessary. However, if an entity concludes otherwise, then it is required to perform the first step of the two-step impairment test.

Under the two-step impairment test, the Partnership assesses the carrying value of goodwill at a reporting unit level based on an estimate of the fair value of the respective reporting unit. Fair value of the reporting unit is estimated using discounted cash flow analyses taking into consideration estimated cash flows in a ten-year projection period and a terminal value calculation at the end of the projection period.  If the fair value of the reporting unit exceeds its carrying value, the goodwill associated with the reporting unit is not considered to be impaired.  If the carrying value of the reporting unit exceeds its fair value, an impairment loss is recognized to the extent that the carrying amount of the associated goodwill, if any, exceeds the implied fair value of the goodwill.

The carrying values of goodwill assigned to the Partnership’s operating segments are as follows:

				Fuel oil and			Natural gas
	Propane			refined fuels			and electricity		Total
Balance as of September 30, 2017
Goodwill	$	1,082,297		$	10,900		$	7,900	$	1,101,097
Accumulated adjustments		—			(6,462	)		—		(6,462	)
	$	1,082,297		$	4,438		$	7,900	$	1,094,635
Fiscal 2018 Activity
Goodwill disposed (2)	$	(1,165	)	$	—		$	—	$	(1,165	)
Balance as of June 30, 2018
Goodwill	$	1,081,132		$	10,900		$	7,900	$	1,099,932
Accumulated adjustments		—			(6,462	)		—		(6,462	)
	$	1,081,132		$	4,438		$	7,900	$	1,093,470

Other intangible assets consist of the following:

	As of
	June 30,			September 30,
	2018			2017
Customer relationships (1) (2)	$	499,433		$	492,656
Non-compete agreements (1)		33,540			31,040
Other		1,967			1,967
		534,940			525,663
Less: accumulated amortization
Customer relationships		(317,024	)		(279,287	)
Non-compete agreements		(27,207	)		(25,242	)
Other		(1,327	)		(1,258	)
		(345,558	)		(305,787	)
	$	189,382		$	219,876

(1) Reflects the impact from the acquisitions (Note 3).

(2) Reflects the impact from the disposition of certain assets and operations in a non-strategic market of the propane

segment (Note 3).

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7. Net Income Per Common Unit

Computations of basic income per Common Unit are performed by dividing net income by the weighted average number of outstanding Common Units, and vested (and unissued) restricted units granted under the Partnership’s Restricted Unit Plans, as defined below, to retirement-eligible grantees.  Computations of diluted income per Common Unit are performed by dividing net income by the weighted average number of outstanding Common Units and unissued restricted units granted under the Restricted Unit Plans.  In computing diluted net income per Common Unit, weighted average units outstanding used to compute basic net income per Common Unit were increased by 237,697 and 183,752 units for the nine months ended June 30, 2018 and June 24, 2017, respectively, to reflect the potential dilutive effect of the unvested restricted units outstanding using the treasury stock method. Diluted loss per unit for the three months ended June 30, 2018 and June 24, 2017 does not include unvested Restricted Units (see Note 10) as their effect would be anti-dilutive.  

8. Long-Term Borrowings

Long-term borrowings consist of the following:

	As of
	June 30,			September 30,
	2018			2017
5.5% senior notes, due June 1, 2024	$	525,000		$	525,000
5.75% senior notes, due March 1, 2025		250,000			250,000
5.875% senior notes due March 1, 2027		350,000			350,000
Revolving Credit Facility, due March 3, 2021		151,145			162,645
Subtotal		1,276,145			1,287,645
Less: unamortized debt issuance costs		(13,967	)		(15,481	)
	$	1,262,178		$	1,272,164

Senior Notes

2024 Senior Notes.  On May 27, 2014, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a public offering of $525,000 in aggregate principal amount of 5.5% senior notes due June 1, 2024 (the “2024 Senior Notes”).  The 2024 Senior Notes were issued at 100% of the principal amount and require semi-annual interest payments in June and December.  The net proceeds from the issuance of the 2024 Senior Notes, along with cash on hand, were used to repurchase, satisfy and discharge all of the Partnership’s then-outstanding 7.5% senior notes due in 2018.

2025 Senior Notes.  On February 25, 2015, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a public offering of $250,000 in aggregate principal amount of 5.75% senior notes due March 1, 2025 (the “2025 Senior Notes”).  The 2025 Senior Notes were issued at 100% of the principal amount and require semi-annual interest payments in March and September.  The net proceeds from the issuance of the 2025 Senior Notes, along with cash on hand, were used to repurchase, satisfy and discharge all of the Partnership’s then-outstanding 7.375% senior notes due in 2020.  

2027 Senior Notes.  On February 14, 2017, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a public offering of $350,000 in aggregate principal amount of 5.875% senior notes due March 1, 2027 (the “2027 Senior Notes”).  The 2027 Senior Notes were issued at 100% of the principal amount and require semi-annual interest payments in March and September.  The net proceeds from the issuance of the 2027 Senior Notes, along with borrowings under the Revolving Credit Facility, were used to repurchase, satisfy and discharge all of the previously outstanding 7.375% senior notes due in 2021.

The Partnership’s obligations under the 2024 Senior Notes, 2025 Senior Notes and 2027 Senior Notes (collectively, the “Senior Notes”) are unsecured and rank senior in right of payment to any future subordinated indebtedness and equally in right of payment with any future senior indebtedness.  The Senior Notes are structurally subordinated to, which means they rank effectively behind, any debt and other liabilities of the Operating Partnership.  The Partnership is permitted to redeem some or all of the Senior Notes at redemption prices and times as specified in the indentures governing the Senior Notes.  The Senior Notes each have a change of control provision that would require the Partnership to offer to repurchase the notes at 101% of the principal amount repurchased, if a change of control, as defined in the indenture, occurs and is followed by a rating decline (a decrease in the rating of the notes by either Moody’s Investors Service or Standard and Poor’s Rating Group by one or more gradations) within 90 days of the consummation of the change of control.

Credit Agreement.  The Operating Partnership has an amended and restated credit agreement, dated March 3, 2016 (the “Amended Credit Agreement”) that provides for a five-year $500,000 revolving credit facility (the “Revolving Credit Facility”) with a maturity date of March 3, 2021, of which $151,145 and $162,645 was outstanding as of June 30, 2018 and September 30, 2017, respectively.  Borrowings under the Revolving Credit Facility may be used for general corporate purposes, including working capital, capital

14

expenditures and acquisitions.  The Operating Partnership has the right to prepay any borrowings under the Revolving Credit Facility, in whole or in part, without penalty at any time prior to maturity.

The Amended Credit Agreement contains certain restrictive and affirmative covenants applicable to the Operating Partnership, its subsidiaries and the Partnership, as well as certain financial covenants, including (a) requiring the Partnership’s Consolidated Interest Coverage Ratio, as defined in the Amended Credit Agreement, to be not less than 2.5 to 1.0 as of the end of any fiscal quarter, (b) prohibiting the Total Consolidated Leverage Ratio, as defined in the Amended Credit Agreement, of the Partnership from being greater than 5.95 to 1.0 for each fiscal quarter ending in December 2017, and March and June 2018, 5.75 to 1.0 for the fiscal quarter ending in September 2018, and 5.5 to 1.0 for the fiscal quarter ending in December 2018 and for each fiscal quarter thereafter, and (c) prohibiting the Senior Secured Consolidated Leverage Ratio, as defined in the Amended Credit Agreement, of the Operating Partnership from being greater than 3.0 to 1.0 as of the end of any fiscal quarter.  

The Partnership and certain subsidiaries of the Operating Partnership act as guarantors with respect to the obligations of the Operating Partnership under the Amended Credit Agreement pursuant to the terms and conditions set forth therein.  The obligations under the Amended Credit Agreement are secured by liens on substantially all of the personal property of the Partnership, the Operating Partnership and their subsidiaries, as well as mortgages on certain real property.

Borrowings under the Revolving Credit Facility bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, LIBOR plus the Applicable Rate, or the base rate, defined as the higher of the Federal Funds Rate plus ½ of 1%, the administrative agent bank’s prime rate, or LIBOR plus 1%, plus in each case the Applicable Rate.  The Applicable Rate is dependent upon the Partnership’s Total Consolidated Leverage Ratio.  As of June 30, 2018, the interest rate for borrowings under the Revolving Credit Facility was approximately 4.8%.  The interest rate and the Applicable Rate will be reset following the end of each calendar quarter.

In connection with a previous credit agreement, the Operating Partnership had entered into an interest rate swap agreement with a notional amount of $100,000, an effective date of June 25, 2013 and a termination date of January 5, 2017.  Under this interest rate swap agreement, the Operating Partnership paid a fixed interest rate of 1.63% to the issuing lender on the notional principal amount outstanding, and the issuing lender paid the Operating Partnership a floating rate, namely LIBOR, on the same notional principal amount.  The interest rate swap was designated as a cash flow hedge.  The Partnership did not enter into a new interest rate swap agreement upon termination.

As of June 30, 2018, the Partnership had standby letters of credit issued under the Revolving Credit Facility of $45,226 which expire periodically through April 30, 2019.

The Amended Credit Agreement and the Senior Notes both contain various restrictive and affirmative covenants applicable to the Operating Partnership, its subsidiaries and the Partnership, respectively, including (i) restrictions on the incurrence of additional indebtedness, and (ii) restrictions on certain liens, investments, guarantees, loans, advances, payments, mergers, consolidations, distributions, sales of assets and other transactions.  Under the Amended Credit Agreement and the indentures governing the Senior Notes, the Operating Partnership and the Partnership are generally permitted to make cash distributions equal to available cash, as defined, as of the end of the immediately preceding quarter, if no event of default exists or would exist upon making such distributions, and with respect to the indentures governing the Senior Notes, the Partnership’s Consolidated Fixed Charge Coverage Ratio, as defined, is greater than 1.75 to 1.  The Partnership and the Operating Partnership were in compliance with all covenants and terms of the Senior Notes and the Amended Credit Agreement as of June 30, 2018.

The aggregate amounts of long-term debt maturities subsequent to June 30, 2018 are as follows: fiscal 2018: $-0-; fiscal 2019: $-0-; fiscal 2020: $-0-; fiscal 2021: $151,145; fiscal 2022: $-0-; and thereafter: $1,125,000.

9. Distributions of Available Cash

The Partnership makes distributions to its partners no later than 45 days after the end of each fiscal quarter in an aggregate amount equal to its Available Cash for such quarter. Available Cash, as defined in the Partnership Agreement, generally means all cash on hand at the end of the respective fiscal quarter less the amount of cash reserves established by the Board of Supervisors in its reasonable discretion for future cash requirements. These reserves are retained for the proper conduct of the Partnership’s business, the payment of debt principal and interest and for distributions during the next four quarters.

On July 26, 2018, the Partnership announced a quarterly distribution of $0.60 per Common Unit, or $2.40 per Common Unit on an annualized basis, in respect of the third quarter of fiscal 2018, payable on August 14, 2018 to holders of record on August 7, 2018.

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10. Unit-Based Compensation Arrangements

The Partnership recognizes compensation cost over the respective service period for employee services received in exchange for an award of equity, or equity-based compensation, based on the grant date fair value of the award.  The Partnership measures liability awards under an equity-based payment arrangement based on remeasurement of the award’s fair value at the conclusion of each interim and annual reporting period until the date of settlement, taking into consideration the probability that the performance conditions will be satisfied.

Restricted Unit Plans.  On July 22, 2009, the Partnership adopted the Suburban Propane Partners, L.P. 2009 Restricted Unit Plan, as amended (the “2009 Restricted Unit Plan”), which authorizes the issuance of Common Units to executives, managers and other employees and members of the Board of Supervisors of the Partnership. The total number of Common Units authorized for issuance under the 2009 Restricted Unit Plan was 2,400,000 as of June 30, 2018.  In accordance with an August 6, 2013 amendment to the 2009 Restricted Unit Plan, unless otherwise stipulated by the Compensation Committee of the Partnership’s Board of Supervisors on or before the grant date, all restricted unit awards granted after the date of the amendment will vest 33.33% on each of the first three anniversaries of the award grant date.  Prior to the August 6, 2013 amendment, unless otherwise stipulated by the Compensation Committee of the Partnership’s Board of Supervisors on or before the grant date, restricted units issued under the 2009 Restricted Unit Plan vest over time with 25% of the Common Units vesting at the end of each of the third and fourth anniversaries of the grant date and the remaining 50% of the Common Units vesting at the end of the fifth anniversary of the grant date.  The 2009 Restricted Unit Plan participants are not eligible to receive quarterly distributions on, or vote, their respective restricted units until vested.  Restricted units cannot be sold or transferred prior to vesting.  The value of the restricted unit is established by the market price of the Common Unit on the date of grant, net of estimated future distributions during the vesting period.  Restricted units are subject to forfeiture in certain circumstances as defined in the 2009 Restricted Unit Plan. Compensation expense for the unvested awards is recognized ratably over the vesting periods and is net of estimated forfeitures.  At the Partnership’s Tri-Annual Meeting held on May 15, 2018, the Unitholders approved the Partnership's 2018 Restricted Unit Plan (the “2018 Restricted Unit Plan” and together with the 2009 Restricted Unit Plan, the “Restricted Unit Plans”) authorizing the issuance of up to 1,800,000 Common Units.  As of June 30, 2018, there were no awards granted under the 2018 Restricted Unit Plan.

During the nine months ended June 30, 2018, the Partnership awarded 424,431 restricted units under the 2009 Restricted Unit Plan at an aggregate grant date fair value of $8,285.  The following is a summary of activity for the 2009 Restricted Unit Plan for the nine months ended June 30, 2018:

				WeightedAverage
	Restricted			Grant Date Fair
	Units			Value Per Unit
Outstanding September 30, 2017		621,045		$	22.10
Awarded		424,431			19.52
Forfeited		(13,992	)		(19.70	)
Vested (with Common Units issued)		(335,253	)		(24.39	)
Outstanding June 30, 2018		696,231		$	19.47

As of June 30, 2018, unrecognized compensation cost related to unvested restricted units awarded under the 2009 Restricted Unit Plan amounted to $4,322.  Compensation cost associated with unvested awards is expected to be recognized over a weighted-average period of one year.  Compensation expense for the 2009 Restricted Unit Plan, net of forfeitures, for the three and nine months ended June 30, 2018 was $1,715 and $6,862, respectively, and $1,372 and $6,209, for the three and nine months ended June 24, 2017, respectively.

Distribution Equivalent Rights Plan.  On January 17, 2017, the Partnership adopted the Distribution Equivalent Rights Plan (the “DER Plan”), which gives the Compensation Committee of the Partnership’s Board of Supervisors discretion to award distribution equivalent rights (“DERs”) to executive officers of the Partnership.  Once awarded, DERs entitle the grantee to a cash payment each time the Board of Supervisors declares a cash distribution on the Partnership’s Common Units, which cash payment will be equal to an amount calculated by multiplying the number of unvested restricted units which are held by the grantee on the record date of the distribution, by the amount of the declared distribution per Common Unit. Compensation expense recognized under the DER Plan for the three and nine months ended June 30, 2018 was $201 and $609, respectively, and $205 and $640 for the three and nine months ended June 24, 2017.

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Long-Term Incentive Plan.  On August 6, 2013, the Partnership adopted the 2014 Long-Term Incentive Plan (“LTIP”).  The LTIP is a non-qualified, unfunded, long-term incentive plan for officers and key employees that provides for payment, in the form of cash, of an award of equity-based compensation at the end of a three-year performance period.  The level of compensation earned under the LTIP is based on the Partnership’s average distribution coverage ratio over the three-year measurement period.  The Partnership’s average distribution coverage ratio is calculated as the Partnership’s average distributable cash flow, as defined by the LTIP, for each of the three years in the measurement period, subject to certain adjustments as set forth in the LTIP, divided by the amount of annualized cash distributions to be paid by the Partnership.

As a result of the quarterly remeasurement of the liability for awards under the LTIP, compensation expense for the three and nine months ended June 30, 2018 reflected expense of $595 and $2,719, respectively, and income of $550 and $2,026 for the three and nine months ended June 24, 2017, respectively. As of June 30, 2018 and September 30, 2017, the Partnership had a liability included within accrued employment and benefit costs (or other liabilities, as applicable) of $4,356 and $1,637, respectively, related to estimated future payments under the LTIP.

11. Commitments and Contingencies

Self-Insurance.  The Partnership is self-insured for general and product, workers’ compensation and automobile liabilities up to predetermined thresholds above which third party insurance applies. As of June 30, 2018 and September 30, 2017, the Partnership had accrued insurance liabilities of $71,303 and $68,581, respectively, representing the total estimated losses under these self-insurance programs. For the portion of the estimated liability that exceeds insurance deductibles, the Partnership records an asset within other assets (or prepaid expenses and other current assets, as applicable) related to the amount of the liability expected to be covered by insurance which amounted to $19,916 and $18,626 as of June 30, 2018 and September 30, 2017.

Legal Matters.  The Partnership’s operations are subject to operating hazards and risks normally incidental to handling, storing and delivering combustible liquids such as propane. The Partnership has been, and will continue to be, a defendant in various legal proceedings and litigation as a result of these operating hazards and risks, and as a result of other aspects of its business. In this regard, the Partnership’s natural gas and electricity business is currently a defendant in two putative class action suits in New York and Pennsylvania. The complaints allege a number of claims regarding pricing to its electricity customers in those states under various consumer statutes and common law. Based on the nature of the allegations under these suits, the Partnership believes that the suits are without merit and is contesting each of these suits vigorously.  With respect to these pending suits, based on the merits of the allegations, a liability for a loss contingency is not required at this time.  Although any litigation is inherently uncertain, based on past experience, the information currently available to the Partnership, and the amount of its accrued insurance liabilities, the Partnership does not believe that currently pending or threatened litigation matters, or known claims or known contingent claims, will have a material adverse effect on its results of operations, financial condition or cash flow.

12. Guarantees

The Partnership has residual value guarantees associated with certain of its operating leases, related primarily to transportation equipment, with remaining lease periods scheduled to expire periodically through fiscal 2028.  Upon completion of the lease period, the Partnership guarantees that the fair value of the equipment will equal or exceed the guaranteed amount, or the Partnership will pay the lessor the difference.  Although the fair value of equipment at the end of its lease term has historically exceeded the guaranteed amounts, the maximum potential amount of aggregate future payments the Partnership could be required to make under these leasing arrangements, assuming the equipment is deemed worthless at the end of the lease term, was $16,407 as of June 30, 2018.  The fair value of residual value guarantees for outstanding operating leases was de minimis as of June 30, 2018 and September 30, 2017.

13. Pension Plans and Other Postretirement Benefits

The following table provides the components of net periodic benefit costs:

	Pension Benefits
	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Interest cost	$	944		$	1,041		$	2,832		$	3,123
Expected return on plan assets		(473	)		(537	)		(1,420	)		(1,611	)
Amortization of net loss		920			1,301			2,762			3,901
Net periodic benefit cost	$	1,391		$	1,805		$	4,174		$	5,413

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	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Interest cost	$	69		$	96		$	208		$	288
Amortization of prior service credits		(124	)		—			(374	)		—
Amortization of net (gain)		(163	)		(98	)		(491	)		(292	)
Net periodic benefit cost	$	(218	)	$	(2	)	$	(657	)	$	(4	)

The Partnership expects to contribute approximately $4,764 to the defined benefit pension plan during fiscal 2018, of which $3,839 was contributed during the nine months ended June 30, 2018. The projected annual contribution requirements related to the Partnership’s postretirement health care and life insurance benefit plan for fiscal 2018 is $1,243, of which $847 was contributed during the nine months ended June 30, 2018.

The Partnership contributes to multi-employer pension plans (“MEPPs”) in accordance with various collective bargaining agreements covering union employees. As one of the many participating employers in these MEPPs, the Partnership is responsible with the other participating employers for any plan underfunding.  As of June 30, 2018 and September 30, 2017, the Partnership’s estimated obligation to these MEPPs was $22,773 and $23,665, respectively, as a result of its voluntary full withdrawal from certain MEPPs.

14. Amounts Reclassified Out of Accumulated Other Comprehensive Income

The following table summarizes amounts reclassified out of accumulated other comprehensive (loss) income for the three and nine months ended June 30, 2018 and June 24, 2017:

	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Cash Flow Hedges
Balance, beginning of period	$	—		$	—		$	—		$	(205	)
Other comprehensive income before reclassifications:
Unrealized (losses)		—			—			—			(10	)
Reclassifications to earnings:
Realized losses (1)		—			—			—			215
Other comprehensive income		—			—			—			205
Balance, end of period	$	—		$	—		$	—		$	—
Pension Benefits
Balance, beginning of period	$	(35,469	)	$	(48,791	)	$	(37,311	)	$	(51,391	)
Reclassifications to earnings:
Amortization of net loss (2)		920			1,301			2,762			3,901
Other comprehensive income		920			1,301			2,762			3,901
Balance, end of period	$	(34,549	)	$	(47,490	)	$	(34,549	)	$	(47,490	)
Postretirement Benefits
Balance, beginning of period	$	8,171		$	5,570		$	8,499		$	5,764
Reclassifications to earnings:
Amortization of net gain (2)		(163	)		(98	)		(491	)		(292	)
Other comprehensive loss		(163	)		(98	)		(491	)		(292	)
Balance, end of period	$	8,008		$	5,472		$	8,008		$	5,472
Accumulated Other Comprehensive Income (Loss)
Balance, beginning of period	$	(27,298	)	$	(43,221	)	$	(28,812	)	$	(45,832	)
Other comprehensive income before reclassifications		—			—			—			(10	)
Reclassifications to earnings		757			1,203			2,271			3,824
Other comprehensive income		757			1,203			2,271			3,814
Balance, end of period	$	(26,541	)	$	(42,018	)	$	(26,541	)	$	(42,018	)

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(1) Reclassification of realized losses on cash flow hedges are recognized in interest expense.

(2) These amounts are included in the computation of net periodic benefit cost.  See Note 13, “Pension Plans and Other Postretirement Benefits.”

15. Income Taxes

For federal income tax purposes, as well as for state income tax purposes in the majority of the states in which the Partnership operates, the earnings attributable to the Partnership and the Operating Partnership are not subject to income tax at the partnership level. With the exception of those states that impose an entity-level income tax on partnerships, the taxable income or loss attributable to the Partnership and to the Operating Partnership, which may vary substantially from the income (loss) before income taxes reported by the Partnership in the condensed consolidated statement of operations, are includable in the federal and state income tax returns of the Common Unitholders. The aggregate difference in the basis of the Partnership’s net assets for financial and tax reporting purposes cannot be readily determined as the Partnership does not have access to each Common Unitholder’s basis in the Partnership.

As described in Note 1, the earnings of the Corporate Entities are subject to corporate level federal and state income tax.  However, based upon past performance, the Corporate Entities are currently reporting an income tax provision composed primarily of minimum state income taxes.  A full valuation allowance has been provided against the deferred tax assets (with the exception of the AMT credit carryforward; see below) based upon an analysis of all available evidence, both negative and positive at the balance sheet date, which, taken as a whole, indicates that it is more likely than not that sufficient future taxable income will not be available to utilize the assets.  Management’s periodic reviews include, among other things, the nature and amount of the taxable income and expense items, the expected timing of when assets will be used or liabilities will be required to be reported and the reliability of historical profitability of businesses expected to provide future earnings. Furthermore, management considered tax-planning strategies it could use to increase the likelihood that the deferred assets will be realized.

On December 22, 2017, the Tax Cuts and Jobs Act (“2017 Act”) was signed into law, which enacted significant changes to U.S. tax and related laws.  Some of the provisions of the 2017 Act that could affect the Partnership, the Operating Partnership and their subsidiaries include, but are not limited to, a reduction of the federal corporate income tax rate from 35% to 21%, limitations on the deductibility of net business interest expense, restrictions on the use of net operating loss carryforwards arising in taxable years beginning after December 31, 2017 and full expensing for certain qualified property.

In the case of a corporation, the 2017 Act made Alternative Minimum Tax (“AMT”) credit carryforwards fully refundable without regard to future taxable income. Accordingly, the Partnership concluded that the existing valuation allowance on the AMT credit carryforwards of the Corporate Entities should be released as part of accounting for tax reform. The reversal of the valuation allowance resulted in a $1,086 discrete deferred tax benefit being recorded during the first quarter of fiscal 2018. The Partnership remeasured all other federal net deferred tax assets of the Corporate Entities using the new 21% federal income tax rate and correspondingly adjusted the full valuation allowance. The blended corporate tax federal rate requirements of Internal Revenue Code Section 15 do not apply because the Corporate Entities are calendar-year tax filers.

The Partnership will continue to analyze the 2017 Act to determine the full effects of the new law on its consolidated financial statements.

16. Segment Information

The Partnership manages and evaluates its operations in four operating segments, three of which are reportable segments: Propane, Fuel Oil and Refined Fuels, and Natural Gas and Electricity. The chief operating decision maker evaluates performance of the operating segments using a number of performance measures, including gross margins and income before interest expense and provision for income taxes (operating profit). Costs excluded from these profit measures are captured in Corporate and include corporate overhead expenses not allocated to the operating segments. Unallocated corporate overhead expenses include all costs of back office support functions that are reported as general and administrative expenses within the condensed consolidated statements of operations. In addition, certain costs associated with field operations support that are reported in operating expenses within the condensed consolidated statements of operations, including purchasing, training and safety, are not allocated to the individual operating segments. Thus, operating profit for each operating segment includes only the costs that are directly attributable to the operations of the individual segment. The accounting policies of the operating segments are otherwise the same as those described in Note 2, “Summary of Significant Accounting Policies,” in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 30, 2017.

The propane segment is primarily engaged in the retail distribution of propane to residential, commercial, industrial and agricultural customers and, to a lesser extent, wholesale distribution to large industrial end users. In the residential and commercial markets, propane is used primarily for space heating, water heating, cooking and clothes drying. Industrial customers use propane generally as

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a motor fuel burned in internal combustion engines that power over-the-road vehicles, forklifts and stationary engines, to fire furnaces and as a cutting gas.  In the agricultural markets, propane is primarily used for tobacco curing, crop drying, poultry brooding and weed control.

The fuel oil and refined fuels segment is primarily engaged in the retail distribution of fuel oil, diesel, kerosene and gasoline to residential and commercial customers for use primarily as a source of heat in homes and buildings.

The natural gas and electricity segment is engaged in the marketing of natural gas and electricity to residential and commercial customers in the deregulated energy markets of New York and Pennsylvania. Under this operating segment, the Partnership owns the relationship with the end consumer and has agreements with the local distribution companies to deliver the natural gas or electricity from the Partnership’s suppliers to the customer.

Activities in the “all other” category include the Partnership’s service business, which is primarily engaged in the sale, installation and servicing of a wide variety of home comfort equipment, particularly in the areas of heating and ventilation.

The following table presents certain data by reportable segment and provides a reconciliation of total operating segment information to the corresponding consolidated amounts for the periods presented:

	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Revenues:
Propane	$	205,400		$	188,406		$	990,344		$	843,519
Fuel oil and refined fuels		15,400			12,886			82,414			69,612
Natural gas and electricity		10,403			11,923			43,942			44,229
All other		10,733			9,680			34,795			33,420
Total revenues	$	241,936		$	222,895		$	1,151,495		$	990,780
Operating income (loss):
Propane (1)	$	28,073		$	11,323		$	245,845		$	201,332
Fuel oil and refined fuels		(891	)		199			10,132			9,875
Natural gas and electricity		2,192			2,806			11,131			11,461
All other		(4,607	)		(5,747	)		(14,821	)		(16,139	)
Corporate		(21,706	)		(19,643	)		(67,248	)		(61,249	)
Total operating income (loss)		3,061			(11,062	)		185,039			145,280
Reconciliation to net (loss) income:
Loss on debt extinguishment		—			—			—			1,567
Interest expense, net		19,512			18,502			58,428			54,820
Provision for (benefit from) income taxes		144			152			(749	)		308
Net (loss) income	$	(16,595	)	$	(29,716	)	$	127,360		$	88,585
Depreciation and amortization:
Propane	$	27,875		$	27,787		$	83,944		$	83,243
Fuel oil and refined fuels		571			625			1,866			1,923
Natural gas and electricity		—			—			—			—
All other		57			76			163			222
Corporate		2,756			3,337			8,620			10,368
Total depreciation and amortization	$	31,259		$	31,825		$	94,593		$	95,756

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	As of
	June 30,		September30,
	2018		2017
Assets:
Propane	$	2,020,928	$	2,066,997
Fuel oil and refined fuels		49,525		49,863
Natural gas and electricity		12,679		12,455
All other		3,576		2,147
Corporate		44,825		39,821
Total assets	$	2,131,533	$	2,171,283

(1) Includes the loss on sale of business of $4,823 for the nine months ended June 30, 2018 (see Note 3).

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following is a discussion of the financial condition and results of operations of the Partnership as of and for the three and nine months ended June 30, 2018. The discussion should be read in conjunction with Management’s Discussion and Analysis of Financial Condition and Results of Operations and the historical consolidated financial statements and notes thereto included in the Annual Report on Form 10-K for the fiscal year ended September 30, 2017.

Executive Overview

The following are factors that regularly affect our operating results and financial condition.  In addition, our business is subject to the risks and uncertainties described in Item 1A included in the Annual Report on Form 10-K for the fiscal year ended September 30, 2017.

Product Costs and Supply

The level of profitability in the retail propane, fuel oil, natural gas and electricity businesses is largely dependent on the difference between retail sales price and our costs to acquire and transport products.  The unit cost of our products, particularly propane, fuel oil and natural gas, is subject to volatility as a result of supply and demand dynamics or other market conditions, including, but not limited to, economic and political factors impacting crude oil and natural gas supply or pricing.  We enter into product supply contracts that are generally one-year agreements subject to annual renewal, and also purchase product on the open market.  We attempt to reduce price risk by pricing product on a short-term basis. Our propane supply contracts typically provide for pricing based upon index formulas using the posted prices established at major supply points such as Mont Belvieu, Texas, or Conway, Kansas (plus transportation costs) at the time of delivery.

To supplement our annual purchase requirements, we may utilize forward fixed price purchase contracts to acquire a portion of the propane that we resell to our customers, which allows us to manage our exposure to unfavorable changes in commodity prices and to assure adequate physical supply. The percentage of contract purchases, and the amount of supply contracted for under forward contracts at fixed prices, will vary from year to year based on market conditions.

Changes in our costs to acquire and transport products can occur rapidly over a short period of time and can impact profitability.  There is no assurance that we will be able to pass on product acquisition and transportation cost increases fully or immediately, particularly when such costs increase rapidly. Therefore, average retail sales prices can vary significantly from year to year as our costs fluctuate with the propane, fuel oil, crude oil and natural gas commodity markets and infrastructure conditions.  In addition, periods of sustained higher commodity and/or transportation prices can lead to customer conservation, resulting in reduced demand for our product.

Seasonality

The retail propane and fuel oil distribution businesses, as well as the natural gas marketing business, are seasonal because these fuels are primarily used for heating in residential and commercial buildings. Historically, approximately two‑thirds of our retail propane volume is sold during the six-month peak heating season from October through March. The fuel oil business tends to experience greater seasonality given its more limited use for space heating and approximately three-fourths of our fuel oil volumes are sold between October and March. Consequently, sales and operating profits are concentrated in our first and second fiscal quarters.  Cash flows from operations, therefore, are greatest during the second and third fiscal quarters when customers pay for product purchased during the winter heating season.  We expect lower operating profits and either net losses or lower net income during the period from April through September (our third and fourth fiscal quarters).  To the extent necessary, we will reserve cash from the second and third quarters for distribution to holders of our Common Units in the fourth quarter and the following fiscal year first quarter.

Weather

Weather conditions have a significant impact on the demand for our products, in particular propane, fuel oil and natural gas, for both heating and agricultural purposes.  Many of our customers rely heavily on propane, fuel oil or natural gas as a heating source.  Accordingly, the volume sold is directly affected by the severity of the winter weather in our service areas, which can vary substantially from year to year.  In any given area, sustained warmer than normal temperatures will tend to result in reduced propane, fuel oil and natural gas consumption, while sustained colder than normal temperatures will tend to result in greater consumption.

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Hedging and Risk Management Activities

We engage in hedging and risk management activities to reduce the effect of price volatility on our product costs and to ensure the availability of product during periods of short supply. We enter into propane forward, options and swap agreements with third parties, and use futures and options contracts traded on the New York Mercantile Exchange (“NYMEX”) to purchase and sell propane, fuel oil and crude oil at fixed prices in the future. The majority of the futures, forward and options agreements are used to hedge price risk associated with propane and fuel oil physical inventory, as well as, in certain instances, forecasted purchases of propane or fuel oil.  In addition, we sell propane and fuel oil to customers at fixed prices, and enter into derivative instruments to hedge a portion of our exposure to fluctuations in commodity prices as a result of selling the fixed price contracts. Forward contracts are generally settled physically at the expiration of the contract whereas futures, options and swap contracts are generally settled at the expiration of the contract through a net settlement mechanism.  Although we use derivative instruments to reduce the effect of price volatility associated with priced physical inventory and forecasted transactions, we do not use derivative instruments for speculative trading purposes. Risk management activities are monitored by an internal Commodity Risk Management Committee, made up of six members of management and reporting to the Audit Committee, through enforcement of our Hedging and Risk Management Policy.

Critical Accounting Policies and Estimates

Our significant accounting policies are summarized in Note 2, “Summary of Significant Accounting Policies,” included within the Notes to Consolidated Financial Statements section of our Annual Report on Form 10-K for the fiscal year ended September 30, 2017.

Certain amounts included in or affecting our consolidated financial statements and related disclosures must be estimated, requiring management to make certain assumptions with respect to values or conditions that cannot be known with certainty at the time the financial statements are prepared. The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“US GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. We are also subject to risks and uncertainties that may cause actual results to differ from estimated results. Estimates are used when accounting for depreciation and amortization of long-lived assets, employee benefit plans, self-insurance and litigation reserves, environmental reserves, allowances for doubtful accounts, asset valuation assessments and valuation of derivative instruments.  We base our estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources.  Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known to us. Management has reviewed these critical accounting estimates and related disclosures with the Audit Committee of our Board of Supervisors.

Results of Operations and Financial Condition

Consistent with the seasonal nature of the propane and fuel oil businesses, we typically experience a net loss in the third quarter of our fiscal year.  Net loss for the third quarter of fiscal 2018 was $16.6 million, or $0.27 per Common Unit, compared to a net loss of $29.7 million, or $0.48 per Common Unit, in the prior year third quarter.  

Net loss and earnings before interest, taxes, depreciation and amortization (“EBITDA”) for the third quarters of fiscal 2018 and 2017 included unrealized (non-cash) mark-to-market adjustments on derivative instruments in both periods. Excluding the effects of the foregoing items, Adjusted EBITDA (as defined and reconciled below) increased $9.1 million, or 42.5%, to $30.5 million for the third quarter of fiscal 2018.

Retail propane gallons sold in the third quarter of fiscal 2018 of 80.5 million gallons increased 3.6% compared to the prior year third quarter. Although weather during the third quarter typically has less of an impact on volumes sold than it does during the heating season, volumes in the third quarter of fiscal 2018 were positively impacted by cooler temperatures, particularly during the month of April.  According to the National Oceanic and Atmospheric Administration, average temperatures (as measured by heating degree days) across all our service territories for the third quarter of fiscal 2018 were 14% cooler than the prior year third quarter, yet 4% warmer than normal.

Revenues in the third quarter of fiscal 2018 of $241.9 million increased $19.0 million, or 8.5%, compared to the prior year third quarter, primarily due to higher propane volumes sold combined with higher retail selling prices associated with higher wholesale product costs.  Average propane prices (basis Mont Belvieu, Texas) and fuel oil prices were 38.8% and 42.0% higher than the prior year third quarter, respectively. Cost of products sold for the third quarter of fiscal 2018 of $95.4 million increased $3.3 million, or 3.6%, compared to the prior year third quarter, primarily due to higher wholesale product costs, and to a lesser extent, higher propane volumes sold. Cost of products sold included a $3.8 million unrealized (non-cash) gain attributable to the mark-to-market adjustment

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for derivative instruments used in risk management activities, compared to a $0.7 million unrealized (non-cash) loss in the prior year third quarter. These unrealized mark-to-market adjustments are excluded from Adjusted EBITDA for both periods.

Combined operating and general and administrative expenses of $112.2 million for the third quarter of fiscal 2018 increased $2.2 million, or 2.0%, compared to the prior year third quarter, primarily due to higher variable operating costs to support higher demand and higher vehicle fuel costs.  

Depreciation and amortization expense of $31.3 million decreased $0.6 million, or 1.8%, compared to the prior year third quarter. Net interest expense of $19.5 million increased $1.0 million, or 5.5%, compared to the prior year third quarter, primarily due to the rise in benchmark interest rates. With the increase in Adjusted EBITDA, combined with a net debt reduction of $11.5 million during the first nine months of fiscal 2018, our Consolidated Leverage Ratio improved to 4.35x as of June 30, 2018, compared to 5.14x as of September 30, 2017.

During the third quarter of fiscal 2018, we closed on the acquisition of a propane operation located in a strategic market for a total purchase price of $11.9 million, which was funded with cash.      

As previously announced on July 26, 2018, the Partnership’s Board of Supervisors has declared a quarterly distribution of $0.60 per Common Unit for the three months ended June 30, 2018.  The distribution is payable on August 14, 2018 to Common Unitholders of record as of August 7, 2018.

Our anticipated cash requirements for the remainder of fiscal 2018 include: (i) maintenance and growth capital expenditures of approximately $9.2 million; (ii) interest and income tax payments of approximately $20.3 million; and (iii) cash distributions of approximately $36.8 million to our Common Unitholders based on the current quarterly distribution rate of $0.60 per Common Unit.  Based on our liquidity position, which includes cash on hand, availability of funds under our Revolving Credit Facility and expected cash flow from operating activities, we expect to have sufficient funds to meet our current and future obligations.

Three Months Ended June 30, 2018 Compared to Three Months Ended June 24, 2017

Revenues

(Dollars and gallons in thousands)	Three Months Ended							Percent
	June 30,		June 24,		Increase			Increase
	2018		2017		(Decrease)			(Decrease)
Revenues
Propane	$	205,400	$	188,406	$	16,994			9.0	%
Fuel oil and refined fuels		15,400		12,886		2,514			19.5	%
Natural gas and electricity		10,403		11,923		(1,520	)		(12.7	)%
All other		10,733		9,680		1,053			10.9	%
Total revenues	$	241,936	$	222,895	$	19,041			8.5	%
Retail gallons sold
Propane		80,491		77,712		2,779			3.6	%
Fuel oil and refined fuels		5,138		5,243		(105	)		(2.0	)%

As discussed above, average temperatures (as measured in heating degrees days) across all of our service territories during the third quarter of fiscal 2018 were 14% cooler than the prior year third quarter, albeit 4% warmer than normal. The increase in heating degrees days for the quarter were concentrated in the month of April with temperatures that were 39% colder than April 2017 and 16% colder than normal, which contributed to an increase in customer demand for heating needs.

Revenues from the distribution of propane and related activities of $205.4 million increased $17.0 million, or 9.0%, compared to the prior year primarily due to higher average retail selling prices and higher volumes sold.  Average propane selling prices increased 8.8% associated with higher wholesale costs, resulting in a $15.5 million increase in revenues.  As a result of the increase in customer demand, retail propane gallons sold increased 2.8 million gallons, or 3.6%, resulting in a $6.1 million increase in revenues.  Included within the propane segment are revenues from other propane activities of $13.3 million, which decreased $4.6 million primarily due to risk management activities, including a lower notional amount of hedging contracts that were settled physically.

Revenues from the distribution of fuel oil and refined fuels of $15.4 million increased $2.5 million, or 19.5%, compared to the prior year third quarter primarily due to higher average selling prices.  During the third quarter of fiscal 2018, average fuel oil and refined fuels selling prices increased 21.6% attributable to higher wholesale costs, resulting in a $2.8 million increase in revenues. Fuel oil and refined fuels gallons sold decreased 0.1 million gallons, or 2.0%, resulting in a $0.3 million decrease in revenues.  

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Revenues in our natural gas and electricity segment of $10.4 million were $1.5 million, or 12.7%, lower thanthe prior year, mainly due to a decrease in electricity usage.

Cost of Products Sold

(Dollars in thousands)	Three Months Ended									Percent
	June 30,			June 24,			Increase			Increase
	2018			2017			(Decrease)			(Decrease)
Cost of products sold
Propane	$	75,098		$	73,893		$	1,205			1.6	%
Fuel oil and refined fuels		11,229			8,545			2,684			31.4	%
Natural gas and electricity		6,168			7,069			(901	)		(12.7	)%
All other		2,897			2,587			310			12.0	%
Total cost of products sold	$	95,392		$	92,094		$	3,298			3.6	%
As a percent of total revenues		39.4	%		41.3	%

The cost of products sold reported in the condensed consolidated statements of operations represents the weighted average unit cost of propane, fuel oil and refined fuels, and natural gas and electricity sold, including transportation costs to deliver product from our supply points to storage or to our customer service centers. Cost of products sold also includes the cost of appliances and related parts sold or installed by our customer service centers computed on a basis that approximates the average cost of the products.  

Given the retail nature of our operations, we maintain a certain level of priced physical inventory to help ensure that our field operations have adequate supply commensurate with the time of year. Our strategy has been, and will continue to be, to keep our physical inventory priced relatively close to market for our field operations. Consistent with past practices, we principally utilize futures and/or options contracts traded on the NYMEX to mitigate the price risk associated with our priced physical inventory.  In addition, we sell propane and fuel oil to customers at fixed prices, and enter into derivative instruments to hedge a portion of our exposure to fluctuations in commodity prices as a result of selling the fixed price contracts. At expiration, the derivative contracts are settled by the delivery of the product to the respective party or are settled by the payment of a net amount equal to the difference between the then market price and the fixed contract price or option exercise price. Under this risk management strategy, realized gains or losses on futures or options contracts, which are reported in cost of products sold, will typically offset losses or gains on the physical inventory once the product is sold (which may or may not occur in the same accounting period).  We do not use futures or options contracts, or other derivative instruments, for speculative trading purposes. Unrealized (non-cash) gains or losses from changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded within cost of products sold.  Cost of products sold excludes depreciation and amortization; these amounts are reported separately within the condensed consolidated statements of operations.

In the commodities markets, average posted propane prices (basis Mont Belvieu, Texas) and fuel oil prices were 38.8% and 42.0% higher than the prior year third quarter, respectively. The net change in the fair value of derivative instruments resulted in a $3.8 million unrealized (non-cash) gain in the third quarter of fiscal 2018 compared to an unrealized (non-cash) loss of $0.7 million in the prior year third quarter, resulting in a decrease of $4.5 million in cost of products sold year-over-year, all of which was reported within the propane segment.  These unrealized mark-to-market adjustments are excluded from Adjusted EBITDA for both periods.

Cost of products sold associated with the distribution of propane and related activities of $75.1 million increased $1.2 million, or 1.6%, compared to the prior year third quarter, primarily due to higher average wholesale costs and higher volumes sold.  Higher average wholesale propane costs and volumes sold contributed to increases in cost of products sold in the propane segment of $15.2 million and $2.4 million, respectively, compared to the prior year. Cost of products sold from other propane activities decreased $11.9 million compared to the prior year primarily due to risk management activities, including a lower notional amount of hedging contracts that were settled physically, and a higher level of realized gains (as a result of the rise in commodity prices) on derivative contracts used to hedge price risk associated with propane product purchases.

Cost of products sold associated with our fuel oil and refined fuels segment of $11.2 million increased $2.7 million, or 31.4%, compared to the prior year third quarter. Higher average fuel oil and refined fuels wholesale costs and slightly lower volumes sold contributed to an increase in cost of products sold of $2.9 million and a decrease of $0.2 million, respectively, compared to the prior year third quarter.  

Cost of products sold in our natural gas and electricity segment of $6.2 million were $0.9 million, or 12.7%, lower than the prior year.

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Total cost of products sold as a percent of total revenues decreased 1.9 percentage points to39.4% from 41.3%primarily due to a decrease in propane costs resulting from risk management activities, including the impact of mark-to-market adjustments on derivative instruments.

Operating Expenses

(Dollars in thousands)	Three Months Ended
	June 30,			June 24,					Percent
	2018			2017			Increase		Increase
Operating expenses	$	97,519		$	97,070		$	449		0.5	%
As a percent of total revenues		40.3	%		43.5	%

All costs of operating our retail distribution and appliance sales and service operations are reported within operating expenses in the condensed consolidated statements of operations. These operating expenses include the compensation and benefits of field and direct operating support personnel, costs of operating and maintaining our vehicle fleet, overhead and other costs of our purchasing, training and safety departments and other direct and indirect costs of operating our customer service centers.

Operating expenses of $97.5 million for the third quarter of fiscal 2018 increased $0.4 million, or 0.5%, compared to $97.1 million in the prior year third quarter. The increase in operating expenses was primarily due to higher variable operating costs to support higher customer demand and higher vehicle fuel costs, which was substantially offset by continued savings from operating efficiencies.

General and Administrative Expenses

(Dollars in thousands)	Three Months Ended
	June 30,			June 24,					Percent
	2018			2017			Increase		Increase
General and administrative expenses	$	14,705		$	12,968		$	1,737		13.4	%
As a percent of total revenues		6.1	%		5.8	%

All costs of our back office support functions, including compensation and benefits for executives and other support functions, as well as other costs and expenses to maintain finance and accounting, treasury, legal, human resources, corporate development and the information systems functions are reported within general and administrative expenses in the condensed consolidated statements of operations.

General and administrative expenses of $14.7 million for the third quarter of fiscal 2018 increased $1.7 million, or 13.4%, compared to the prior year third quarter primarily due to higher variable compensation expense associated with higher earnings and higher professional services fees.  

Depreciation and Amortization

(Dollars in thousands)	Three Months Ended
	June 30,			June 24,						Percent
	2018			2017			Decrease			Decrease
Depreciation and amortization	$	31,259		$	31,825		$	(566	)		(1.8	)%
As a percent of total revenues		12.9	%		14.3	%

Depreciation and amortization expense of $31.3 million in the third quarter of fiscal 2018 decreased $0.6 million, or 1.8%, primarily as a result of accelerated depreciation recorded in the prior year for assets taken out of service.

Interest Expense, net

(Dollars in thousands)	Three Months Ended
	June 30,			June 24,					Percent
	2018			2017			Increase		Increase
Interest expense, net	$	19,512		$	18,502		$	1,010		5.5	%
As a percent of total revenues		8.1	%		8.3	%

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Net interest expense of $19.5 million in the third quarter of fiscal 2018 was $1.0 million higher than the prior year quarter, primarily due to an increase in benchmark interest rates on borrowingsunder our Revolving Credit Facility.See Liquidity and Capital Resources below for additional discussion.

EBITDA and Adjusted EBITDA

EBITDA represents net income before deducting interest expense, income taxes, depreciation and amortization.  Adjusted EBITDA represents EBITDA excluding the unrealized net gain or loss on mark-to-market activity for derivative instruments and other items, as applicable, as provided in the table below. Our management uses EBITDA and Adjusted EBITDA as supplemental measures of operating performance and we are including them because we believe that they provide our investors and industry analysts with additional information that we determined is useful to evaluate our operating results. EBITDA and Adjusted EBITDA are not recognized terms under US GAAP and should not be considered as an alternative to net income or net cash provided by operating activities determined in accordance with US GAAP.  Because EBITDA and Adjusted EBITDA as determined by us excludes some, but not all, items that affect net income, they may not be comparable to EBITDA and Adjusted EBITDA or similarly titled measures used by other companies.

The following table sets forth our calculations of EBITDA and Adjusted EBITDA:

(Dollars in thousands)	Three Months Ended
	June 30,			June 24,
	2018			2017
Net loss	$	(16,595	)	$	(29,716	)
Add:
Provision for income taxes		144			152
Interest expense, net		19,512			18,502
Depreciation and amortization		31,259			31,825
EBITDA		34,320			20,763
Unrealized (non-cash) (gains) losses on changes in fair value of derivatives		(3,806	)		655
Adjusted EBITDA	$	30,514		$	21,418

Nine Months Ended June 30, 2018 Compared to Nine Months Ended June 24, 2017

Revenues

(Dollars and gallons in thousands)	Nine Months Ended							Percent
	June 30,		June 24,		Increase			Increase
	2018		2017		(Decrease)			(Decrease)
Revenues
Propane	$	990,344	$	843,519	$	146,825			17.4	%
Fuel oil and refined fuels		82,414		69,612		12,802			18.4	%
Natural gas and electricity		43,942		44,229		(287	)		(0.6	)%
All other		34,795		33,420		1,375			4.1	%
Total revenues	$	1,151,495	$	990,780	$	160,715			16.2	%
Retail gallons sold
Propane		375,201		350,188		25,013			7.1	%
Fuel oil and refined fuels		27,905		27,251		654			2.4	%

Average temperatures (as measured in heating degree days) across all of our service territories for the first nine months of fiscal 2018 were 6% warmer than normal and 9% cooler than the comparable prior year period.  The cooler temperatures compared to the prior year were experienced throughout the majority of our service territories, which contributed to an increase in customer demand for heating needs.

Revenues from the distribution of propane and related activities of $990.3 million increased $146.8 million, or 17.4%, primarily due to higher average retail selling prices and higher volumes sold.  Average propane selling prices increased 11.0% associated with higher wholesale propane costs, resulting in a $91.9 million increase in revenues.  Retail propane gallons sold increased 25.0 million gallons, or 7.1%, resulting in a $55.6 million increase in revenues.  Included within the propane segment are revenues from other propane activities of $64.9 million, which decreased $0.7 million.

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Revenues from the distribution of fuel oil and refined fuels of $82.4 million increased $12.8 million, or 18.4%, primarily due to higher average selling prices and higher volumes sold. Average selling prices for fuel oil and refined fuels increased 15.5%, resulting in an $11.0 million increase in revenues.  Fuel oil and refined fuels gallons sold increased 0.7 million gallons, or 2.4%, resulting in a $1.8 million increase in revenues.

Revenues in our natural gas and electricity segment of $43.9 million decreased $0.3 million, or 0.6%, compared to the prior year.

Cost of Products Sold

(Dollars in thousands)	Nine Months Ended
	June 30,			June 24,					Percent
	2018			2017			Increase		Increase
Cost of products sold
Propane	$	413,923		$	322,251		$	91,672		28.4	%
Fuel oil and refined fuels		57,193			44,935			12,258		27.3	%
Natural gas and electricity		26,236			25,876			360		1.4	%
All other		9,871			9,665			206		2.1	%
Total cost of products sold	$	507,223		$	402,726		$	104,497		25.9	%
As a percent of total revenues		44.0	%		40.6	%

In the commodities markets, average posted propane prices (basis Mont Belvieu, Texas) and fuel oil prices were 38.7% and 28.5% higher than the first nine months of the prior year, respectively.  The net change in the fair value of derivative instruments during the period resulted in unrealized (non-cash) losses of $1.4 million and $2.7 million in the first nine months of fiscal 2018 and 2017, respectively, resulting in a decrease of $1.3 million in cost of products sold compared to the prior year, all of which was reported within the propane segment.  These unrealized mark-to-market adjustments are excluded from Adjusted EBITDA for both periods.

Cost of products sold associated with the distribution of propane and related activities of $413.9 million increased $91.7 million, or 28.4%.  Higher average wholesale costs resulted in an increase of $96.0 million compared to the prior year, while the increase in volumes sold increased costs by $21.3 million.  Cost of products sold from other propane activities decreased $24.3 million compared to the prior year, primarily due to realized gains (as a result of the rise in commodity prices) on derivative contracts used to hedge price risk associated with propane product purchases.

Cost of products sold associated with our fuel oil and refined fuels segment of $57.2 million increased $12.3 million, or 27.3%.  Higher average wholesale costs resulted in an increase of $11.2 million and higher volumes sold resulted in an increase of $1.1 million over the prior year period.  

Cost of products sold in our natural gas and electricity segment of $26.2 million increased $0.4 million, or 1.4%, compared to the prior year.

Total cost of products sold as a percent of total revenues increased 3.4 percentage points to 44.0% from 40.6% primarily due to the year-over-year rise in wholesale propane costs outpacing the year-over-year increase in average propane selling prices.

Operating Expenses

(Dollars in thousands)	Nine Months Ended
	June 30,			June 24,					Percent
	2018			2017			Increase		Increase
Operating expenses	$	310,132		$	306,839		$	3,293		1.1	%
As a percent of total revenues		26.9	%		31.0	%

Operating expenses of $310.1 million for the first nine months of fiscal 2018 increased $3.3 million, or 1.1%, compared to the prior year period. The increase in operating expenses was primarily due to higher variable operating costs attributable to an increase in deliveries and other operational activities to support higher customer demand, higher variable compensation associated with higher operating earnings, and higher general insurance expenses, all of which were substantially offset by continued savings from operating efficiencies.

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General and Administrative Expenses

(Dollars in thousands)	Nine Months Ended
	June 30,			June 24,					Percent
	2018			2017			Increase		Increase
General and administrative expenses	$	49,685		$	40,179		$	9,506		23.7	%
As a percent of total revenues		4.3	%		4.1	%

General and administrative expenses of $49.7 million for the first nine months of fiscal 2018 increased $9.5 million, or 23.7%, compared to the prior year period, primarily due to higher variable compensation expense associated with higher earnings.

Depreciation and Amortization

(Dollars in thousands)	Nine Months Ended
	June 30,			June 24,						Percent
	2018			2017			Decrease			Decrease
Depreciation and amortization	$	94,593		$	95,756		$	(1,163	)		(1.2	)%
As a percent of total revenues		8.2	%		9.7	%

Depreciation and amortization expense of $94.6 million for the first nine months of fiscal 2018 decreased $1.2 million, or 1.2%, primarily as a result of accelerated depreciation expense recorded in the prior year for assets taken out of service.

Interest Expense, net

(Dollars in thousands)	Nine Months Ended
	June 30,			June 24,					Percent
	2018			2017			Increase		Increase
Interest expense, net	$	58,428		$	54,820		$	3,608		6.6	%
As a percent of total revenues		5.1	%		5.5	%

Net interest expense of $58.4 million increased $3.6 million, or 6.6%, compared to the prior year period, primarily due to a higher average level of outstanding borrowings and, to a lesser extent, an increase in benchmark interest rates on outstanding borrowings under our Revolving Credit Facility.  These items were partially offset by savings from the refinancing of our previously outstanding 7.375% senior notes due August 1, 2021 with the issuance of 5.875% senior notes due March 1, 2027 in the second quarter of fiscal 2017. See Liquidity and Capital Resources below for additional discussion.

Loss on Sale of Business

On December 8, 2017, we sold certain assets and operations in a non-strategic market of our propane segment for $2.8 million plus working capital consideration, resulting in a loss of $4.8 million that was recognized during the first quarter of fiscal 2018. The corresponding net assets and results of operations were not material to our condensed consolidated results of operations, financial position and cash flows.

Loss on Debt Extinguishment

On February 14, 2017, we repurchased, satisfied and discharged all of our previously outstanding 2021 Senior Notes with net proceeds from the issuance of the 2027 Senior Notes and borrowings under the Revolving Credit Facility, pursuant to a tender offer and redemption. In connection with this tender offer and redemption during the second quarter of fiscal 2017, we recognized a loss on the extinguishment of debt of $1.6 million, consisting of $15.1 million for the redemption premium and related fees, as well as the write-off of $2.3 million and ($15.8) million in unamortized debt origination costs and unamortized premium, respectively.

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EBITDA and Adjusted EBITDA

The following table sets forth our calculations of EBITDA and Adjusted EBITDA:

(Dollars in thousands)	Nine Months Ended
	June 30,			June 24,
	2018			2017
Net income	$	127,360		$	88,585
Add:
(Benefit from) provision for income taxes		(749	)		308
Interest expense, net		58,428			54,820
Depreciation and amortization		94,593			95,756
EBITDA		279,632			239,469
Unrealized (non-cash) losses on changes in fair value of derivatives		1,421			2,708
Loss on debt extinguishment		—			1,567
Loss on sale of business		4,823			—
Adjusted EBITDA	$	285,876		$	243,744

Liquidity and Capital Resources

Analysis of Cash Flows

Operating Activities. Net cash provided by operating activities for the first nine months of fiscal 2018 and fiscal 2017 was $156.1 million and $124.0 million, respectively. The $32.1 million year-over-year increase in net cash provided by operating activities was primarily attributable to higher earnings (discussed above), offset to an extent by a larger increase in working capital during the first nine months of fiscal 2018 compared to the prior year, stemming from the impact of higher wholesale product costs.

Investing Activities.  Net cash used in investing activities of $32.8 million for the first nine months of fiscal 2018 consisted of capital expenditures of $25.8 million (including approximately $15.7 million to support the growth of operations and $10.1 million for maintenance expenditures) and $14.9 million used in the acquisition of two retail propane businesses (see Item 1, Note 3 of this Quarterly Report); partially offset by $5.1 million in proceeds from the sale of other property, plant and equipment and $2.8 million in proceeds from the sale of assets and operations in a non-strategic market.

Net cash used in investing activities of $18.2 million for the first nine months of fiscal 2017 consisted of capital expenditures of $22.0 million (including approximately $13.6 million to support the growth of operations and $8.4 million for maintenance expenditures), partially offset by $3.8 million in net proceeds from the sale of property, plant and equipment.

Financing Activities. Net cash used in financing activities for the first nine months of fiscal 2018 of $122.7 million reflected $110.3 million paid for the quarterly distributions to Common Unitholders at a rate of $0.60 per Common Unit paid in respect of the fourth quarter of fiscal 2017 and first and second quarters of fiscal 2018, other financing activities of $0.8 million and net repayments of borrowings under the Revolving Credit Facility of $11.5 million.

Net cash used in financing activities for the first nine months of fiscal 2017 of $139.9 million reflects the quarterly distributions to Common Unitholders at a rate of $0.8875 per Common Unit paid in respect of the fourth quarter of fiscal 2016 and the first and second quarters of fiscal 2017.  In addition, cash used in financing activities included proceeds of $350.0 million from the issuance of the 2027 Senior Notes in February 2017 which were used, along with borrowings under the Revolving Credit Facility, to repurchase, satisfy and discharge all of the previously outstanding 2021 Senior Notes, as well as to pay tender premiums and other related fees of $14.7 million and debt issuance costs of $6.1 million, pursuant to a tender offer and redemption.  Total net borrowings under the Revolving Credit Facility were $41.1 million for the first nine months of fiscal 2017, which were used to fund a portion of our cash needs.  During the third quarter of fiscal 2017, we paid $1.0 million for costs incurred to amend the Revolving Credit Facility.

Summary of Long-Term Debt Obligations and Revolving Credit Lines

As of June 30, 2018, our long-term debt consisted of $525.0 million in aggregate principal amount of 5.5% senior notes due June 1, 2024, $250.0 million in aggregate principal amount of 5.75% senior notes due March 1, 2025, $350.0 million in aggregate principal amount of 5.875% senior notes due March 1, 2027 and $151.1 million outstanding under our Revolving Credit Facility.  See Item 1, Note 8 of this Quarterly Report.

The aggregate amounts of long-term debt maturities subsequent to June 30, 2018 are as follows: fiscal 2018: $-0-; fiscal 2019: $-0-; fiscal 2020: $-0-; fiscal 2021: $151.1 million; fiscal 2022: $-0-; and thereafter: $1,125.0 million.

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Partnership Distributions

We are required to make distributions in an amount equal to all of our Available Cash, as defined in our Third Amended and Restated Partnership Agreement, as amended (the “Partnership Agreement”), no more than 45 days after the end of each fiscal quarter to holders of record on the applicable record dates.  Available Cash, as defined in the Partnership Agreement, generally means all cash on hand at the end of the respective fiscal quarter less the amount of cash reserves established by the Board of Supervisors in its reasonable discretion for future cash requirements. These reserves are retained for the proper conduct of our business, the payment of debt principal and interest and for distributions during the next four quarters.  The Board of Supervisors reviews the level of Available Cash on a quarterly basis based upon information provided by management.

On July 26, 2018, we announced a quarterly distribution of $0.60 per Common Unit, or $2.40 on an annualized basis, in respect of the third quarter of fiscal 2018, payable on August 14, 2018 to holders of record on August 7, 2018.

Other Commitments

We have a noncontributory, cash balance format, defined benefit pension plan which was frozen to new participants effective January 1, 2000.  Effective January 1, 2003, the defined benefit pension plan was amended such that future service credits ceased and eligible employees would receive interest credits only toward their ultimate retirement benefit.  We also provide postretirement health care and life insurance benefits for certain retired employees under a plan that was frozen to new participants effective March 31, 1998.  At June 30, 2018, we had a liability for the defined benefit pension plan and accrued retiree health and life benefits of $34.6 million and $11.5 million, respectively.

We are self-insured for general and product, workers’ compensation and automobile liabilities up to predetermined thresholds above which third party insurance applies.  At June 30, 2018, we had accrued insurance liabilities of $71.3 million, and a receivable of $19.9 million related to the amount of the liability expected to be covered by insurance.

Legal Matters

See Item 1, Note 11, Legal Matters subsection of this Quarterly Report.

Off-Balance Sheet Arrangements

Guarantees

See Item 1, Note 12 of this Quarterly Report.

Recently Issued Accounting Pronouncements

See Item 1, Note 2, Recently Issued Accounting Pronouncements subsection of this Quarterly Report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Price Risk

We enter into product supply contracts that are generally one-year agreements subject to annual renewal, and also purchase product on the open market.  Our propane supply contracts typically provide for pricing based upon index formulas using the posted prices established at major supply points such as Mont Belvieu, Texas, or Conway, Kansas (plus transportation costs) at the time of delivery. In addition, to supplement our annual purchase requirements, we may utilize forward fixed price purchase contracts to acquire a portion of the propane that we resell to our customers, which allows us to manage our exposure to unfavorable changes in commodity prices and to ensure adequate physical supply. The percentage of contract purchases, and the amount of supply contracted for under forward contracts at fixed prices, will vary from year to year based on market conditions.  In certain instances, and when market conditions are favorable, we are able to purchase product under our supply arrangements at a discount to the market.

Product cost changes can occur rapidly over a short period of time and can impact profitability. We attempt to reduce commodity price risk by pricing product on a short-term basis. The level of priced, physical product maintained in storage facilities and at our customer service centers for immediate sale to our customers will vary depending on several factors, including, but not limited to, price, supply and demand dynamics for a given time of the year.  Typically, our on hand priced position does not exceed more than four to eight weeks of our supply needs, depending on the time of the year.  In the course of normal operations, we routinely enter into contracts such as forward priced physical contracts for the purchase or sale of propane and fuel oil that, under accounting rules for derivative instruments and hedging activities, qualify for and are designated as normal purchase or normal sale contracts. Such contracts are exempted from fair value accounting and are accounted for at the time product is purchased or sold under the related contract.

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Under our hedging and risk management strategies, we enter into a combination of exchange-traded futures and options contracts and, in certain instances, over-the-counter options and swap contracts (collectively, “derivative instruments”) to manage the price risk associated with physical product and with future purchases of the commodities used in our operations, principally propane and fuel oil, as well as to help ensure the availability of product during periods of high demand.  In addition, we sell propane and fuel oil to customers at fixed prices, and enter into derivative instruments to hedge a portion of our exposure to fluctuations in commodity prices as a result of selling the fixed price contracts. We do not use derivative instruments for speculative or trading purposes.  Futures and swap contracts require that we sell or acquire propane or fuel oil at a fixed price for delivery at fixed future dates.  An option contract allows, but does not require, its holder to buy or sell propane or fuel oil at a specified price during a specified time period. However, the writer of an option contract must fulfill the obligation of the option contract, should the holder choose to exercise the option.  At expiration, the contracts are settled by the delivery of the product to the respective party or are settled by the payment of a net amount equal to the difference between the then market price and the fixed contract price or option exercise price. To the extent that we utilize derivative instruments to manage exposure to commodity price risk and commodity prices move adversely in relation to the contracts, we could suffer losses on those derivative instruments when settled.  Conversely, if prices move favorably, we could realize gains. Under our hedging and risk management strategy, realized gains or losses on derivative instruments will typically offset losses or gains on the physical inventory once the product is sold to customers at market prices, or delivered to customers as it pertains to fixed price contracts.

Futures are traded with brokers of the NYMEX and require daily cash settlements in margin accounts.  Forward contracts are generally settled at the expiration of the contract term by physical delivery, and swap and options contracts are generally settled at expiration through a net settlement mechanism.  Market risks associated with our derivative instruments are monitored daily for compliance with our Hedging and Risk Management Policy which includes volume limits for open positions. Open inventory positions are reviewed and managed daily as to exposures to changing market prices.

Credit Risk

Exchange-traded futures and options contracts are guaranteed by the NYMEX and, as a result, have minimal credit risk.  We are subject to credit risk with over-the-counter forward, swap and options contracts to the extent the counterparties do not perform.  We evaluate the financial condition of each counterparty with which we conduct business and establish credit limits to reduce exposure to the risk of non-performance by our counterparties.

Interest Rate Risk

A portion of our borrowings bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, LIBOR, plus an applicable margin or the base rate, defined as the higher of the Federal Funds Rate plus ½ of 1% or the agent bank’s prime rate, or LIBOR plus 1%, plus the applicable margin. The applicable margin is dependent on the level of our total consolidated leverage (the total ratio of debt to consolidated EBITDA). Therefore, we are subject to interest rate risk on the variable component of the interest rate.  From time to time, we enter into interest rate swap agreements to manage a part of our variable interest rate risk.  The interest rate swaps are designated as cash flow hedges. Changes in the fair value of the interest rate swaps are recognized in other comprehensive income (“OCI”) until the hedged item is recognized in earnings. At June 30, 2018, we were not party to an interest rate swap agreement.

Derivative Instruments and Hedging Activities

All of our derivative instruments are reported on the balance sheet at their fair values. On the date that derivative instruments are entered into, we make a determination as to whether the derivative instrument qualifies for designation as a hedge. Changes in the fair value of derivative instruments are recorded each period in current period earnings or OCI, depending on whether a derivative instrument is designated as a hedge and, if so, the type of hedge. For derivative instruments designated as cash flow hedges, we formally assess, both at the hedge contract’s inception and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows of hedged items.  Changes in the fair value of derivative instruments designated as cash flow hedges are reported in OCI to the extent effective and reclassified into earnings during the same period in which the hedged item affects earnings.  The mark-to-market gains or losses on ineffective portions of cash flow hedges are immediately recognized in earnings.  Changes in the fair value of derivative instruments that are not designated as cash flow hedges, and that do not meet the normal purchase and normal sale exemption, are recorded in earnings as they occur. Cash flows associated with derivative instruments are reported as operating activities within the condensed consolidated statement of cash flows.

Sensitivity Analysis

In an effort to estimate our exposure to unfavorable market price changes in commodities related to our open positions under derivative instruments, we developed a model that incorporates the following data and assumptions:

A. The fair value of open positions as of June 30, 2018.

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B. The market prices for the underlying commodities used to determine A. above were adjusted adversely by a hypothetical 10% change and compared to the fair value amounts in A. above to project the potential negative impact on earnings that would be recognized for the respective scenario.

Based on the sensitivity analysis described above, a hypothetical 10% adverse change in market prices for open derivative instruments as of June 30, 2018 indicates a decrease in potential future net gains of $6.4 million. See also Item 7A of our Annual Report on Form 10-K for the fiscal year ended September 30, 2017. The above hypothetical change does not reflect the worst case scenario. Actual results may be significantly different depending on market conditions and the composition of the open position portfolio.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

The Partnership maintains disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) that are designed to provide reasonable assurance that information required to be disclosed in the Partnership’s filings and submissions under the Exchange Act is recorded, processed, summarized and reported within the periods specified in the rules and forms of the SEC and that such information is accumulated and communicated to the Partnership’s management, including its principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

The Partnership completed an evaluation under the supervision and with participation of the Partnership’s management, including the Partnership’s principal executive officer and principal financial officer, of the effectiveness of the design and operation of the Partnership’s disclosure controls and procedures as of June 30, 2018.  Based on this evaluation, the Partnership’s principal executive officer and principal financial officer have concluded that as of June 30, 2018, such disclosure controls and procedures were effective to provide the reasonable assurance described above.

Changes in Internal Control Over Financial Reporting

There have not been any changes in the Partnership’s internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act) during the quarter ended June 30, 2018 that have materially affected or are reasonably likely to materially affect its internal control over financial reporting.

33

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

None.

ITEM 1A. RISK FACTORS

There have been no material changes to the risk factors disclosed in Item 1A in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 30, 2017.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4. MINE SAFETY DISCLOSURES

Not applicable.

ITEM 5. OTHER INFORMATION

None.

34

ITEM 6. EXHIBITS

(a) Exhibits

INDEX TO EXHIBITS

The exhibits listed on this Exhibit Index are filed as part of this Quarterly Report.  Exhibits required to be filed by Item 601 of Regulation S-K, which are not listed below, are not applicable.

Exhibit Number	Description
3.1	Amendment No. 2, dated January 24, 2018, to the Third Amended and Restated Agreement of Limited Partnership of the Partnership dated as of October 19, 2006, as amended as of July 31, 2007.  (Incorporated by reference to Exhibit 3.1 to the Partnership’s Current Report on Form 8-K filed on January 24, 2018).
3.2	Amendment No. 2, dated January 24, 2018, to the Third Amended and Restated Agreement of Limited Partnership of the Operating Partnership dated as of October 19, 2006, as amended as of June 24, 2009.  (Incorporated by reference to Exhibit 3.2 to the Partnership’s Current Report on Form 8-K filed on January 24, 2018).
10.1	2018 Restricted Unit Plan of Suburban Propane Partners, L.P. (Incorporated by reference to Exhibit 10.1 to the Partnership’s Current Report on Form 8-K filed on May 16, 2018).
10.2	Fifth Amendment to the Retirement Savings and Investment Plan of Suburban Propane (effective April 1, 2018).  (Filed herewith). #
31.1	Certification of the President and Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. (Filed herewith).
31.2	Certification of the Chief Financial Officer and Chief Accounting Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. (Filed herewith).
32.1	Certification of the President and Chief Executive Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. (Furnished herewith).
32.2	Certification of the Chief Financial Officer and Chief Accounting Officer Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. (Furnished herewith).
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB	XBRL Taxonomy Extension Label Linkbase Document
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document

35

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	SUBURBAN PROPANE PARTNERS, L.P.
August 9, 2018	By:	/s/ MICHAEL A. KUGLIN
Date		Michael A. Kuglin
		Chief Financial Officer and Chief Accounting Officer
August 9, 2018	By:	/s/ DANIEL S. BLOOMSTEIN
Date		Daniel S. Bloomstein
		Vice President and Controller

36

EX-10.2

Exhibit 10.2

FIFTH AMENDMENT

TO

SUBURBAN PROPANE RETIREMENT SAVINGS & INVESTMENT PLAN

Pursuant to Article XI of the Suburban Propane Retirement Savings & Investment Plan effective January 1, 2013, said Plan is amended as set forth herein effective as of April 1, 2018.

               FIRST:         Article V of the Plan is restated in its entirety, as attached hereto.

               SECOND:     In all other respects, the Plan is ratified and approved.

               IN WITNESS WHEREOF, the duly authorized Members of the Benefits Administration Committee have adopted this amendment this 15th day of May 2018.

/s/ DANIEL S. BLOOMSTEIN	/s/ STEVEN C. BOYD
Daniel S. Bloomstein	Steven C. Boyd
/s/ A. DAVIN D’AMBROSIO	/s/ MICHAEL A. KUGLIN
A. Davin D’Ambrosio	Michael A. Kuglin
/s/ SANDRA N. ZWICKEL
Sandra N. Zwickel

ARTICLE V ‑ BENEFITS

5.01 Retirement Benefits:

(a) Normal Retirement:  A Participant is entitled to receive his Normal Retirement Benefit as of his Normal Retirement Date.

(i) Normal Retirement Date shall mean the later of the date on which the Participant attains age 65 or the 5th anniversary of his Date of Participation.

(ii) Normal Retirement Benefit shall mean the entire balance of the Participant’s account, valued in accordance with the provisions of Section 5.05, and distributed in accordance with the provisions of Articles VI and VII of the Plan.

(b) Late Retirement:  A Participant whose employment continues beyond his Normal Retirement Date shall continue to participate in this Plan until his actual retirement and is entitled to receive, as his Late Retirement Benefit, the entire balance remaining in his account, valued in accordance with the provisions of Section 5.05, and distributed in accordance with the provisions of Articles VI and VII of the Plan.

(c)Early Retirement:  No Early Retirement Benefit is provided under the terms of this Plan.

5.02 RESERVED

5.03  Death Benefit:  Upon the death of a Participant prior to his separation from service with the Employer (including while on a leave of absence for Qualified Military Service, in accordance with Section 12.04), the entire balance of his account, valued in accordance with the provisions of Section 5.05, shall be distributable, as a Death Benefit, as soon as administratively feasible and in accordance with the provisions of Articles VII of the Plan.

5.04  Deferred Vested Benefit:  The Vested Portion of a Participant’s Accounts shall be 100% at all times, such that he shall be entitled to the entire balance in his account, valued in accordance with the provisions of Section 5.05, if his participation ceases for any reason whatsoever. Distribution of such deferred vested benefit shall be made in accordance with the provisions of Articles VI and VII.

5.05 Valuation Date:  The assets of the Plan shall be valued as of each day on which the New York Stock Exchange is open for trading.  For purposes of distribution, the value of a Participant’s account shall be determined as of the valuation date coincident with or immediately preceding the date on which (a) the Participant or other payee becomes entitled to distribution by virtue of the occurrence of a distributable event, (b) consent of the Participant or other payee is provided (if such consent is required), and (c) the Participant or other payee completes and submits all required distribution election forms, if any, which date shall be referred to as the “benefit entitlement date.”  

5.06  “Year of Vested Service”:  A Participant shall be credited with a Year of Vested Service, for purposes of Section 5.04, for any Plan Year, or any comparable twelve-month period prior to the Effective Date of the Plan, during which he has been credited with an Hour of Service.

5.07  Forfeiture for Cause:  No vested benefit under this Plan shall be subject to forfeiture for cause.

V-1

5.08  In-Service Withdrawals:  Any Participant may make withdrawals, at any time and without regard to termination of employment with the Employer, from his Employer Contribution Account, and Voluntary Nondeductible Contribution Account, or from amounts transferred to this Plan from a prior plan or by rollover pursuant to Article XIII. Any Participant who has attained age 59-1/2 may make withdrawals from any or all of his Accounts prior to his termination of employment with the Employer; provided, however, that such withdrawals shall be made from the following sources in the following order: (a) amounts transferred to this Plan from a prior plan or by rollover pursuant to Article XIII, (b) Voluntary Nondeductible Contribution Account, (c) Employer Contribution Account and/or Employer Matching Contribution Account, and (d) Elective Deferral Contribution Account.

5.09  Qualified Reservist Distribution:  Effective as of January 1, 2011, any Participant, regardless of age, who is a member of the reserves and who is ordered or called to active duty for a period in excess of 179 days or for an indefinite period may withdraw all or any portion of his Elective Deferral Contribution Account, provided that such withdrawal is made during the period beginning on the date of such order or call to active duty and ending at the close of the active duty period.

V-2

EX-31.1

EXHIBIT 31.1

Certification of the President and Chief Executive Officer

Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

I, Michael A. Stivala, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Suburban Propane Partners, L.P.;

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 control 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 control over financial reporting, or caused such internal control 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 Supervisors:

(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.

August 9, 2018	By:	/s/ MICHAEL A. STIVALA
		Michael A. Stivala
		President and Chief Executive Officer

EX-31.2

EXHIBIT 31.2

Certification of the Chief Financial Officer and Chief Accounting Officer

Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

I, Michael A. Kuglin, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Suburban Propane Partners, L.P.;

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 control 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 control over financial reporting, or caused such internal control 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 Supervisors:

(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.

August 9, 2018	By:	/s/ MICHAEL A. KUGLIN
		Michael A. Kuglin
		Chief Financial Officer and Chief Accounting Officer

EX-32.1

EXHIBIT 32.1

Certification of the President and Chief Executive Officer 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 Suburban Propane Partners, L.P. (the “Partnership”) on Form 10-Q for the period ended June 30, 2018 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael A. Stivala, President and Chief Executive Officer of the Partnership, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

(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 results of operations of the Partnership.

By:	/s/ MICHAEL A. STIVALA
	Michael A. Stivala
	President and Chief Executive Officer
	August 9, 2018

EX-32.2

EXHIBIT 32.2

Certification of the Chief Financial Officer and Chief Accounting Officer

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 Suburban Propane Partners, L.P. (the “Partnership”) on Form 10-Q for the period ended June 30, 2018 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael A. Kuglin, Chief Financial Officer and Chief Accounting Officer of the Partnership, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to my knowledge:

(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 results of operations of the Partnership.

By:	/s/ MICHAEL A. KUGLIN
	Michael A. Kuglin
	Chief Financial Officer and Chief Accounting Officer
	August 9, 2018

XML

Document and Entity Information - shares	9 Months Ended
	Jun. 30, 2018	Aug. 06, 2018
Document And Entity Information [Abstract]
Entity Registrant Name	SUBURBAN PROPANE PARTNERS LP
Entity Central Index Key	0001005210
Current Fiscal Year End Date	--09-29
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		61,405,409
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q3
Document Type	10-Q
Trading Symbol	SPH
Amendment Flag	false
Document Period End Date	Jun. 30, 2018

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Current assets:
Cash and cash equivalents	$ 3,439	$ 2,789
Accounts receivable, less allowance for doubtful accounts of $4,643 and $3,044, respectively	88,047	65,683
Inventories	49,838	53,220
Other current assets	22,435	17,801
Total current assets	163,759	139,493
Property, plant and equipment, net	659,581	692,627
Goodwill	1,093,470	1,094,635
Other intangible assets, net	189,382	219,876
Other assets	25,341	24,652
Total assets	2,131,533	2,171,283
Current liabilities:
Accounts payable	31,098	38,652
Accrued employment and benefit costs	28,756	27,402
Customer deposits and advances	45,487	97,023
Accrued interest	14,550	13,682
Other current liabilities	33,782	33,607
Total current liabilities	153,673	210,366
Long-term borrowings	1,262,178	1,272,164
Accrued insurance	57,576	54,921
Other liabilities	79,819	80,850
Total liabilities	1,553,246	1,618,301
Commitments and contingencies
Partners’ capital:
Common Unitholders (61,405 and 61,105 units issued and outstanding at June 30, 2018 and September 30, 2017, respectively)	604,828	581,794
Accumulated other comprehensive loss	(26,541)	(28,812)
Total partners’ capital	578,287	552,982
Total liabilities and partners’ capital	$ 2,131,533	$ 2,171,283

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Current assets:
Allowance for doubtful accounts	$ 4,643	$ 3,044
Partners’ capital:
Common units issued (in units)	61,405,000	61,105,000
Common units outstanding (in units)	61,405,409	61,105,000

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 24, 2017	Jun. 30, 2018	Jun. 24, 2017
Revenues
Total Revenues	$ 241,936	$ 222,895	$ 1,151,495	$ 990,780
Costs and expenses
Cost of products sold	95,392	92,094	507,223	402,726
Operating	97,519	97,070	310,132	306,839
General and administrative	14,705	12,968	49,685	40,179
Depreciation and amortization	31,259	31,825	94,593	95,756
Total Expenses	238,875	233,957	961,633	845,500
Loss on sale of business			4,823	0
Operating income (loss)	3,061	(11,062)	185,039	145,280
Loss on debt extinguishment	0	0	0	1,567
Interest expense, net	19,512	18,502	58,428	54,820
(Loss) income before (benefit from) provision for income taxes	(16,451)	(29,564)	126,611	88,893
(Benefit from) provision for income taxes	144	152	(749)	308
Net (loss) income	$ (16,595)	$ (29,716)	$ 127,360	$ 88,585
Net (loss) income per Common Unit - basic	$ (0.27)	$ (0.48)	$ 2.07	$ 1.45
Weighted average number of Common Units outstanding - basic	61,598	61,290	61,542	61,227
Net (loss) income per Common Unit - diluted	$ (0.27)	$ (0.48)	$ 2.06	$ 1.44
Weighted average number of Common Units outstanding - diluted	61,598	61,290	61,780	61,410
Propane [Member]
Revenues
Total Revenues	$ 205,400	$ 188,406	$ 990,344	$ 843,519
Fuel Oil and Refined Fuels [Member]
Revenues
Total Revenues	15,400	12,886	82,414	69,612
Natural Gas and Electricity [Member]
Revenues
Total Revenues	10,403	11,923	43,942	44,229
All Other [Member]
Revenues
Total Revenues	$ 10,733	$ 9,680	$ 34,795	$ 33,420

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 24, 2017	Jun. 30, 2018	Jun. 24, 2017
Statement Of Income And Comprehensive Income [Abstract]
Net (loss) income	$ (16,595)	$ (29,716)	$ 127,360	$ 88,585
Other comprehensive income:
Net unrealized (losses) on cash flow hedges	0	0	0	(10)
Reclassification of realized losses on cash flow hedges into earnings	0	0	0	215
Amortization of net actuarial losses and prior service credits into earnings	757	1,203	2,271	3,609
Other comprehensive income	757	1,203	2,271	3,814
Total comprehensive (loss) income	$ (15,838)	$ (28,513)	$ 129,631	$ 92,399

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2018	Jun. 24, 2017
Cash flows from operating activities:
Net income	$ 127,360	$ 88,585
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization	94,593	95,756
Loss on sale of business	4,823	0
Loss on debt extinguishment	0	1,567
Other, net	7,065	7,271
Changes in assets and liabilities:
Accounts receivable	(21,932)	(19,143)
Inventories	3,545	3,492
Other current and noncurrent assets	(5,111)	(5,193)
Accounts payable	(6,434)	(2,826)
Accrued employment and benefit costs	1,355	6,925
Customer deposits and advances	(51,536)	(49,652)
Contributions to defined benefit pension plan	(3,839)	(7,542)
Other current and noncurrent liabilities	6,227	4,738
Net cash provided by operating activities	156,116	123,978
Cash flows from investing activities:
Capital expenditures	(25,847)	(22,004)
Acquisition of businesses	(14,873)	0
Proceeds from sale of business	2,800	0
Proceeds from sale of property, plant and equipment	5,143	3,829
Net cash (used in) investing activities	(32,777)	(18,175)
Cash flows from financing activities:
Proceeds from long-term borrowings	0	350,000
Repayments of long-term borrowings (includes premium and fees)	0	(360,931)
Proceeds from borrowings under revolving credit facility	283,700	273,240
Repayments of borrowings under revolving credit facility	(295,200)	(232,095)
Issuance costs associated with long-term borrowings	0	(7,064)
Partnership distributions	(110,342)	(162,347)
Other, net	(847)	(736)
Net cash (used in) financing activities	(122,689)	(139,933)
Net increase (decrease) in cash and cash equivalents	650	(34,130)
Cash and cash equivalents at beginning of period	2,789	37,341
Cash and cash equivalents at end of period	$ 3,439	$ 3,211

XML

CONDENSED CONSOLIDATED STATEMENT OF PARTNERS' CAPITAL (unaudited) - 9 months ended Jun. 30, 2018 - USD ($) shares in Thousands, $ in Thousands	Total	Common Unitholders [Member]	Accumulated Other Comprehensive (Loss) [Member]
Balance at Sep. 30, 2017	$ 552,982	$ 581,794	$ (28,812)
Balance (in units) at Sep. 30, 2017		61,105
Net income	127,360	$ 127,360
Other comprehensive income	2,271		2,271
Partnership distributions	(110,342)	$ (110,342)
Common Units issued under Restricted Unit Plans (in units)		300
Compensation cost recognized under Restricted Unit Plans, net of forfeitures	6,016	$ 6,016
Balance at Jun. 30, 2018	$ 578,287	$ 604,828	$ (26,541)
Balance (in units) at Jun. 30, 2018		61,405

XML

Partnership Organization and Formation

9 Months Ended

Jun. 30, 2018

Partnership Organization And Formation [Abstract]

Partnership Organization and Formation

1. Partnership Organization and Formation

Suburban Propane Partners, L.P. (the “Partnership”) is a publicly traded Delaware limited partnership principally engaged, through its operating partnership and subsidiaries, in the retail marketing and distribution of propane, fuel oil and refined fuels, as well as the marketing of natural gas and electricity in deregulated markets.  In addition, to complement its core marketing and distribution businesses, the Partnership services a wide variety of home comfort equipment, particularly for heating and ventilation.  The publicly traded limited partner interests in the Partnership are evidenced by common units traded on the New York Stock Exchange (“Common Units”), with 61,405,409 Common Units outstanding at June 30, 2018.  The holders of Common Units are entitled to participate in distributions and exercise the rights and privileges available to limited partners under the Third Amended and Restated Agreement of Limited Partnership (the “Partnership Agreement”), as amended.  Rights and privileges under the Partnership Agreement include, among other things, the election of all members of the Board of Supervisors and voting on the removal of the general partner.

Suburban Propane, L.P. (the “Operating Partnership”), a Delaware limited partnership, is the Partnership’s operating subsidiary formed to operate the propane business and assets.  In addition, Suburban Sales & Service, Inc. (the “Service Company”), a subsidiary of the Operating Partnership, was formed to operate the service work and appliance and parts businesses of the Partnership.  The Operating Partnership, together with its direct and indirect subsidiaries, accounts for substantially all of the Partnership’s assets, revenues and earnings.  The Partnership, the Operating Partnership and the Service Company commenced operations in March 1996 in connection with the Partnership’s initial public offering.

The general partner of both the Partnership and the Operating Partnership is Suburban Energy Services Group LLC (the “General Partner”), a Delaware limited liability company, the sole member of which is the Partnership’s Chief Executive Officer.  Other than as a holder of 784 Common Units that will remain in the General Partner, the General Partner does not have any economic interest in the Partnership or the Operating Partnership.

The Partnership’s fuel oil and refined fuels, natural gas and electricity and services businesses are structured as either limited liability companies that are treated as corporations or corporate entities (collectively referred to as the “Corporate Entities”) and, as such, are subject to corporate level U.S. income tax.

Suburban Energy Finance Corp., a direct 100%-owned subsidiary of the Partnership, was formed on November 26, 2003 to serve as co-issuer, jointly and severally with the Partnership, of the Partnership’s senior notes.

XML

Basis of Presentation

9 Months Ended

Jun. 30, 2018

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Basis of Presentation

2. Basis of Presentation

Principles of Consolidation.  The condensed consolidated financial statements include the accounts of the Partnership, the Operating Partnership and all of its direct and indirect subsidiaries.  All significant intercompany transactions and account balances have been eliminated.  The Partnership consolidates the results of operations, financial condition and cash flows of the Operating Partnership as a result of the Partnership’s 100% limited partner interest in the Operating Partnership.

The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”).  They include all adjustments that the Partnership considers necessary for a fair statement of the results of operations, financial position and cash flows for the interim periods presented.  Such adjustments consist only of normal recurring items, unless otherwise disclosed.  These financial statements should be read in conjunction with the financial statements included in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 30, 2017.  Due to the seasonal nature of the Partnership’s operations, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.

Fiscal Period.  The Partnership uses a 52/53 week fiscal year which ends on the last Saturday in September.  The Partnership’s fiscal quarters are generally thirteen weeks in duration.  When the Partnership’s fiscal year is 53 weeks long, as was the case for fiscal 2017, the corresponding fourth quarter is fourteen weeks in duration.

Revenue Recognition.  Sales of propane, fuel oil and refined fuels are recognized at the time product is delivered to the customer.  Revenue from the sale of appliances and equipment is recognized at the time of sale or when installation is complete, as applicable.  Revenue from repairs, maintenance and other service activities is recognized upon completion of the service.  Revenue from annually billed service contracts is recognized ratably over the service period.  Revenue from the natural gas and electricity business is recognized based on customer usage as determined by meter readings for amounts delivered, some of which may be unbilled at the end of each accounting period.  Revenue from annually billed tank fees is deferred at the time of billings and recognized on a straight-line basis over one year.

Fair Value Measurements.  The Partnership measures certain of its assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants – in either the principal market or the most advantageous market.  The principal market is the market with the greatest level of activity and volume for the asset or liability.

The common framework for measuring fair value utilizes a three-level hierarchy to prioritize the inputs used in the valuation techniques to derive fair values.  The basis for fair value measurements for each level within the hierarchy is described below with Level 1 having the highest priority and Level 3 having the lowest.

• Level 1: Quoted prices in active markets for identical assets or liabilities.

• Level 2: Quoted prices in active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations in which all significant inputs are observable in active markets.

• Level 3: Valuations derived from valuation techniques in which one or more significant inputs are unobservable.

Business Combinations.  The Partnership accounts for business combinations using the acquisition method and accordingly, the assets and liabilities of the acquired entities are recorded at their estimated fair values at the acquisition date.  Goodwill represents the excess of the purchase price over the fair value of the net assets acquired, including the amount assigned to identifiable intangible assets.  The primary drivers that generate goodwill are the value of synergies between the acquired entities and the Partnership, and the acquired assembled workforce, neither of which qualifies as an identifiable intangible asset.  Identifiable intangible assets with finite lives are amortized over their useful lives.  The results of operations of acquired businesses are included in the consolidated financial statements from the acquisition date.  The Partnership expenses all acquisition-related costs as incurred.

Use of Estimates.  The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“US GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.  Estimates have been made by management in the areas of self-insurance and litigation reserves, pension and other postretirement benefit liabilities and costs, valuation of derivative instruments, depreciation and amortization of long-lived assets, asset impairment assessments, tax valuation allowances, allowances for doubtful accounts, and purchase price allocation for acquired businesses.  The Partnership uses Society of Actuaries life expectancy information when developing the annual mortality assumptions for the pension and postretirement benefit plans, which are used to measure net periodic benefit costs and the obligation under these plans.  Actual results could differ from those estimates, making it reasonably possible that a material change in these estimates could occur in the near term.

Reclassifications.  Certain prior period amounts have been reclassified to conform with the current period presentation.  See Recently Adopted Accounting Pronouncements, below.

Recently Issued Accounting Pronouncements.  In March 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” (“ASU 2017-07”).  This update provides guidance on the capitalization, presentation and disclosure of net benefit costs.  ASU 2017-07 is effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019 and will be applied retrospectively upon adoption.  The Partnership is currently evaluating the impact that the standard will have on the Partnership’s consolidated statements of operations.

In January 2017, the FASB issued ASU 2017-04, “Simplifying the Test for Goodwill Impairment” (“ASU 2017-04”).  This update eliminates the second of the two-step goodwill impairment test, as described in Note 6, “Goodwill and Other Intangible Assets.”  Instead, an entity should perform its annual or interim goodwill impairment test by comparing the fair value of a reporting unit to its carrying amount and recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value, not to exceed the total amount of goodwill allocated to the reporting unit.  ASU 2017-04 is effective for the first interim period within annual reporting periods beginning after December 15, 2019, which will be the Partnership’s first quarter of fiscal 2021.  Early adoption of ASU 2017-04 is permitted.  The Partnership does not expect that the adoption of ASU 2017-04 will have a material impact on the Partnership’s consolidated financial statements.

In August 2016, the FASB issued ASU 2016-15, “Classification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”).  This update addresses eight specific cash flow issues and is intended to reduce diversity in practice on how certain cash receipts and cash payments are presented and classified in the statement of cash flows.  ASU 2016-15 is effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019.  Early adoption of ASU 2016-15 is permitted.  The Partnership is currently evaluating the impact of adopting the standard on the Partnership’s consolidated statements of cash flows.

In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”). The standard amends the existing accounting standards for lease accounting, including requiring lessees to recognize most leases on their balance sheets and making targeted changes to lessor accounting. ASU 2016-02 is effective for the first interim period within annual reporting periods beginning after December 15, 2018, which will be the Partnership’s first quarter of fiscal 2020.  Early adoption of ASU 2016-02 is permitted. The new leases standard requires a modified retrospective transition approach for all leases existing at, or entered into after, the date of initial application, with an option to use certain transition relief. The Partnership is currently evaluating the impact of adopting ASU 2016-02 on the Partnership’s consolidated financial statements.

In May 2014, the FASB issued ASU 2014-09 “Revenue from Contracts with Customers” (“ASU 2014-09”).  This update provides a principles-based approach to revenue recognition, requiring revenue recognition to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  The ASU provides a five-step model to be applied to all contracts with customers. The five steps are to identify the contract(s) with the customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract and recognize revenue when each performance obligation is satisfied. On July 9, 2015, the FASB finalized a one-year deferral of the effective date of ASU 2014-09.  The revenue standard is therefore effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019.  Early adoption as of the original effective date is permitted.  ASU 2014-09 can be applied either retrospectively to each prior reporting period presented or with the cumulative effect of initially applying the update recognized at the date of the initial application along with additional disclosures.  While the Partnership is still in the process of evaluating the potential impact of ASU 2014-09, it does not expect its adoption will have a material impact on the Partnership’s consolidated financial statements.

Recently Adopted Accounting Pronouncements.During the first quarter of fiscal 2018, the Partnership adopted new accounting guidance regarding stock-based compensation under ASU 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”).  Cash payments made to the taxing authorities on employees’ behalf for withheld shares are now presented as financing activities on the condensed consolidated statement of cash flows, rather than operating activities.  The amounts paid to federal and state taxing authorities were $847 and $736 for the nine months ended June 30, 2018 and June 24, 2017, respectively.

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Acquisition and Disposition of Businesses

9 Months Ended

Jun. 30, 2018

Business Combination Disposition [Abstract]

Acquisition and Disposition of Businesses

3. Acquisition and Disposition of Businesses

On November 7, 2017, the Operating Partnership acquired the propane assets and operations of a propane retailer headquartered in California for $4,871, including $750 for non-compete consideration, plus working capital acquired. As of June 30, 2018, $4,251 was paid and the remainder of the purchase price will be funded in accordance with the terms of the asset purchase and non-compete agreements.  The acquisition was consummated pursuant to the Partnership’s strategic growth initiatives. The purchase price allocation and results of operations of the acquired business were not material to the Partnership’s condensed consolidated financial position and statement of operations.

On December 8, 2017, the Operating Partnership sold certain assets and operations in a non-strategic market of its propane segment for $2,800, plus working capital consideration, resulting in a loss of $4,823 that was recognized during the first quarter of fiscal 2018, principally for the allocated goodwill and other identifiable intangible assets associated with this business. The corresponding net assets and results of operations were not material to the Partnership’s condensed consolidated results of operations, financial position and cash flows.

On April 5, 2018, the Operating Partnership acquired the propane assets and operations of two affiliated propane retailers headquartered in Florida for $11,900, including $1,750 for non-compete consideration, plus working capital acquired. As of June 30, 2018, $10,622 was paid and the remainder of the purchase price will be funded in accordance with the terms of the asset purchase and non-compete agreements.  The acquisition was consummated pursuant to the Partnership’s strategic growth initiatives.  The preliminary purchase price allocation and results of operations of the acquired business were not material to the Partnership’s condensed consolidated financial position and statement of operations.

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Financial Instruments and Risk Management

9 Months Ended

Jun. 30, 2018

Fair Value Disclosures [Abstract]

Financial Instruments and Risk Management

4. Financial Instruments and Risk Management

Cash and Cash Equivalents.  The Partnership considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents.  The carrying amount approximates fair value because of the short-term maturity of these instruments.

Derivative Instruments and Hedging Activities

Commodity Price Risk.  Given the retail nature of its operations, the Partnership maintains a certain level of priced physical inventory to help ensure its field operations have adequate supply commensurate with the time of year.  The Partnership’s strategy is to keep its physical inventory priced relatively close to market for its field operations.  The Partnership enters into a combination of exchange-traded futures and option contracts and, in certain instances, over-the-counter options and swap contracts (collectively, “derivative instruments”) to hedge price risk associated with propane and fuel oil physical inventories, as well as future purchases of propane or fuel oil used in its operations and to help ensure adequate supply during periods of high demand.  In addition, the Partnership sells propane and fuel oil to customers at fixed prices, and enters into derivative instruments to hedge a portion of its exposure to fluctuations in commodity prices as a result of selling the fixed price contracts.  Under this risk management strategy, realized gains or losses on derivative instruments will typically offset losses or gains on the physical inventory once the product is sold or delivered as it pertains to fixed price contracts.  All of the Partnership’s derivative instruments are reported on the condensed consolidated balance sheet at their fair values.  In addition, in the course of normal operations, the Partnership routinely enters into contracts such as forward priced physical contracts for the purchase or sale of propane and fuel oil that qualify for and are designated as normal purchase or normal sale contracts.  Such contracts are exempted from the fair value accounting requirements and are accounted for at the time product is purchased or sold under the related contract.  The Partnership does not use derivative instruments for speculative trading purposes.  Market risks associated with derivative instruments are monitored daily for compliance with the Partnership’s Hedging and Risk Management Policy which includes volume limits for open positions.  Priced on-hand inventory is also reviewed and managed daily as to exposures to changing market prices.

On the date that derivative instruments are entered into, other than those designated as normal purchases or normal sales, the Partnership makes a determination as to whether the derivative instrument qualifies for designation as a hedge.  Changes in the fair value of derivative instruments are recorded each period in current period earnings or other comprehensive income (“OCI”), depending on whether the derivative instrument is designated as a hedge and, if so, the type of hedge.  For derivative instruments designated as cash flow hedges, the Partnership formally assesses, both at the hedge contract’s inception and on an ongoing basis, whether the hedge contract is highly effective in offsetting changes in cash flows of hedged items.  Changes in the fair value of derivative instruments designated as cash flow hedges are reported in OCI to the extent effective and reclassified into earnings during the same period in which the hedged item affects earnings.  The mark-to-market gains or losses on ineffective portions of cash flow hedges are recognized in earnings immediately.  Changes in the fair value of derivative instruments that are not designated as cash flow hedges, and that do not meet the normal purchase and normal sale exemption, are recorded within earnings as they occur.  Cash flows associated with derivative instruments are reported as operating activities within the condensed consolidated statement of cash flows.

Interest Rate Risk.  A portion of the Partnership’s borrowings bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, LIBOR plus an applicable margin or the base rate, defined as the higher of the Federal Funds Rate plus ½ of 1% or the agent bank’s prime rate, or LIBOR plus 1%, plus the applicable margin.  The applicable margin is dependent on the level of the Partnership’s total leverage (the ratio of total debt to income before deducting interest expense, income taxes, depreciation and amortization (“EBITDA”)).  Therefore, the Partnership is subject to interest rate risk on the variable component of the interest rate.  From time to time, the Partnership manages part of its variable interest rate risk by entering into interest rate swap agreements. The interest rate swaps have been designated as, and are accounted for as, cash flow hedges.  The fair value of the interest rate swaps are determined using an income approach, whereby future settlements under the swaps are converted into a single present value, with fair value being based on the value of current market expectations about those future amounts.  Changes in the fair value are recognized in OCI until the hedged item is recognized in earnings.  However, due to changes in the underlying interest rate environment, the corresponding value in OCI is subject to change prior to its impact on earnings.

Valuation of Derivative Instruments.  The Partnership measures the fair value of its exchange-traded options and futures contracts using quoted market prices found on the New York Mercantile Exchange (the “NYMEX”) (Level 1 inputs); the fair value of its swap contracts using quoted forward prices, and the fair value of its interest rate swaps using model-derived valuations driven by observable projected movements of the 3-month LIBOR (Level 2 inputs); and the fair value of its over-the-counter options contracts using Level 3 inputs.  The Partnership’s over-the-counter options contracts are valued based on an internal option model.  The inputs utilized in the model are based on publicly available information as well as broker quotes.  The significant unobservable inputs used in the fair value measurements of the Partnership’s over-the-counter options contracts are interest rate and market volatility.

The following summarizes the fair value of the Partnership’s derivative instruments and their location in the condensed consolidated balance sheets as of June 30, 2018 and September 30, 2017, respectively:

	As of June 30, 2018			As of September 30, 2017
Asset Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity-related derivatives	Other current assets	$	10,953	Other current assets	$	11,164
	Other assets		158	Other assets		771
		$	11,111		$	11,935
Liability Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity-related derivatives	Other current liabilities	$	4,962	Other current liabilities	$	1,978
	Other liabilities		—	Other liabilities		432
		$	4,962		$	2,410

The following summarizes the reconciliation of the beginning and ending balances of assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Nine Months Ended						Nine Months Ended
	June 30, 2018						June 24, 2017
	Assets			Liabilities			Assets			Liabilities
Beginning balance of over-the-counter options	$	4,108		$	737		$	809		$	—
Beginning balance realized during the period		(3,277	)		(737	)		(589	)		—
Contracts purchased during the period		1,352			158			—			—
Change in the fair value of outstanding contracts		(800	)		—			(115	)		—
Ending balance of over-the-counter options	$	1,383		$	158		$	105		$	—

As of June 30, 2018 and September 30, 2017, the Partnership’s outstanding commodity-related derivatives had a weighted average maturity of approximately four and five months, respectively.

The effect of the Partnership’s derivative instruments on the condensed consolidated statements of operations and the condensed consolidated statements of comprehensive income, as applicable, for the three and nine months ended June 30, 2018 and June 24, 2017 are as follows:

	Three Months Ended June 30, 2018					Three Months Ended June 24, 2017
Derivatives in Cash Flow	Gains (Losses) Recognized  in OCI		Gains (Losses) Reclassified from Accumulated OCI into Income			Gains (Losses) Recognized  in OCI		Gains (Losses) Reclassified from Accumulated OCI into Income
Hedging Relationships	(Effective Portion)		Location	Amount		(Effective Portion)		Location	Amount
Interest rate swap	$	—	Interest expense	$	—	$	—	Interest expense	$	—
Derivatives Not Designated as Hedging Instruments			Unrealized Gains (Losses) Recognized in Income					Unrealized Gains (Losses) Recognized in Income
			Location	Amount				Location	Amount
Commodity-related    derivatives			Cost of products sold	$	3,806			Cost of products sold	$	(655	)

Nine Months Ended June 30, 2018

Nine Months Ended June 24, 2017

Derivatives in Cash Flow

Gains (Losses) Recognized  in OCI

Gains (Losses) Reclassified from Accumulated OCI into Income

Gains (Losses) Recognized  in OCI

Gains (Losses) Reclassified from Accumulated OCI into Income

Hedging Relationships

(Effective Portion)

Location

Amount

(Effective Portion)

Location

Amount

Interest rate swap

$

—

Interest expense

$

—

$

(10

)

Interest expense

$

(215

)

Derivatives Not Designated as Hedging Instruments

Unrealized Gains (Losses) Recognized in Income

Unrealized Gains (Losses) Recognized in Income

Location

Amount

Location

Amount

Commodity-related    derivatives

Cost of products sold

$

(1,421

)

Cost of products sold

$

(2,708

)

The following table presents the fair value of the Partnership’s recognized derivative assets and liabilities on a gross basis and amounts offset on the condensed consolidated balance sheets subject to enforceable master netting arrangements or similar agreements:

	As of June 30, 2018							As of September 30, 2017
						Net amounts							Net amounts
						presented in the							presented in the
	Gross amounts		Effects of netting			balance sheet		Gross amounts		Effects of netting			balance sheet
Asset Derivatives
Commodity-related derivatives	$	19,688	$	(8,577	)	$	11,111	$	16,378	$	(4,443	)	$	11,935
Liability Derivatives
Commodity-related derivatives	$	13,539	$	(8,577	)	$	4,962	$	6,853	$	(4,443	)	$	2,410

The Partnership had no cash collateral requirements as of June 30, 2018 and September 30, 2017 with its brokers for outstanding commodity-related derivatives.

Bank Debt and Senior Notes.  The fair value of the borrowings under the Revolving Credit Facility (defined below in Note 8) approximates the carrying value since the interest rates are adjusted quarterly to reflect market conditions. Based upon quoted market prices (a Level 1 input), the fair value of the Senior Notes (also defined below in Note 8) of the Partnership are as follows:

	As of
	June 30,		September 30,
	2018		2017
5.5% senior notes due June 1, 2024	$	511,875	$	527,888
5.75% senior notes due March 1, 2025		240,625		248,750
5.875% senior notes due March 1, 2027		327,250		349,125
	$	1,079,750	$	1,125,763

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Inventories

9 Months Ended

Jun. 30, 2018

Inventory Disclosure [Abstract]

Inventories

5. Inventories

Inventories are stated at the lower of cost or market. Cost is determined using a weighted average method for propane, fuel oil and refined fuels and natural gas, and a standard cost basis for appliances, which approximates average cost. Inventories consist of the following:

	As of
	June 30,		September 30,
	2018		2017
Propane, fuel oil and refined fuels and natural gas	$	48,210	$	51,844
Appliances		1,628		1,376
	$	49,838	$	53,220

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Goodwill and Other Intangible Assets

9 Months Ended

Jun. 30, 2018

Goodwill And Intangible Assets Disclosure [Abstract]

Goodwill and Other Intangible Assets

6. Goodwill and Other Intangible Assets

Goodwill represents the excess of the purchase price over the fair value of net assets acquired. Goodwill is subject to an impairment review at a reporting unit level, on an annual basis as of the end of fiscal July of each year, or when an event occurs or circumstances change that would indicate potential impairment.

The Partnership has the option to first assess qualitative factors to determine whether the existence of events or circumstances leads to a determination that it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, after assessing the totality of events or circumstances, an entity determines it is not more likely than not that the fair value of a reporting unit is less than its carrying amount, then performing the two-step impairment test is unnecessary. However, if an entity concludes otherwise, then it is required to perform the first step of the two-step impairment test.

Under the two-step impairment test, the Partnership assesses the carrying value of goodwill at a reporting unit level based on an estimate of the fair value of the respective reporting unit. Fair value of the reporting unit is estimated using discounted cash flow analyses taking into consideration estimated cash flows in a ten-year projection period and a terminal value calculation at the end of the projection period.  If the fair value of the reporting unit exceeds its carrying value, the goodwill associated with the reporting unit is not considered to be impaired.  If the carrying value of the reporting unit exceeds its fair value, an impairment loss is recognized to the extent that the carrying amount of the associated goodwill, if any, exceeds the implied fair value of the goodwill.

The carrying values of goodwill assigned to the Partnership’s operating segments are as follows:

				Fuel oil and			Natural gas
	Propane			refined fuels			and electricity		Total
Balance as of September 30, 2017
Goodwill	$	1,082,297		$	10,900		$	7,900	$	1,101,097
Accumulated adjustments		—			(6,462	)		—		(6,462	)
	$	1,082,297		$	4,438		$	7,900	$	1,094,635
Fiscal 2018 Activity
Goodwill disposed (2)	$	(1,165	)	$	—		$	—	$	(1,165	)
Balance as of June 30, 2018
Goodwill	$	1,081,132		$	10,900		$	7,900	$	1,099,932
Accumulated adjustments		—			(6,462	)		—		(6,462	)
	$	1,081,132		$	4,438		$	7,900	$	1,093,470

Other intangible assets consist of the following:

	As of
	June 30,			September 30,
	2018			2017
Customer relationships (1) (2)	$	499,433		$	492,656
Non-compete agreements (1)		33,540			31,040
Other		1,967			1,967
		534,940			525,663
Less: accumulated amortization
Customer relationships		(317,024	)		(279,287	)
Non-compete agreements		(27,207	)		(25,242	)
Other		(1,327	)		(1,258	)
		(345,558	)		(305,787	)
	$	189,382		$	219,876

(1) Reflects the impact from the acquisitions (Note 3).

(2) Reflects the impact from the disposition of certain assets and operations in a non-strategic market of the propane

segment (Note 3).

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Net Income Per Common Unit

9 Months Ended

Jun. 30, 2018

Earnings Per Share [Abstract]

Net Income Per Common Unit

7. Net Income Per Common Unit

Computations of basic income per Common Unit are performed by dividing net income by the weighted average number of outstanding Common Units, and vested (and unissued) restricted units granted under the Partnership’s Restricted Unit Plans, as defined below, to retirement-eligible grantees.  Computations of diluted income per Common Unit are performed by dividing net income by the weighted average number of outstanding Common Units and unissued restricted units granted under the Restricted Unit Plans.  In computing diluted net income per Common Unit, weighted average units outstanding used to compute basic net income per Common Unit were increased by 237,697 and 183,752 units for the nine months ended June 30, 2018 and June 24, 2017, respectively, to reflect the potential dilutive effect of the unvested restricted units outstanding using the treasury stock method. Diluted loss per unit for the three months ended June 30, 2018 and June 24, 2017 does not include unvested Restricted Units (see Note 10) as their effect would be anti-dilutive.  

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Long-Term Borrowings

9 Months Ended

Jun. 30, 2018

Debt Disclosure [Abstract]

Long Term Borrowings

8. Long-Term Borrowings

Long-term borrowings consist of the following:

	As of
	June 30,			September 30,
	2018			2017
5.5% senior notes, due June 1, 2024	$	525,000		$	525,000
5.75% senior notes, due March 1, 2025		250,000			250,000
5.875% senior notes due March 1, 2027		350,000			350,000
Revolving Credit Facility, due March 3, 2021		151,145			162,645
Subtotal		1,276,145			1,287,645
Less: unamortized debt issuance costs		(13,967	)		(15,481	)
	$	1,262,178		$	1,272,164

Senior Notes

2024 Senior Notes.  On May 27, 2014, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a public offering of $525,000 in aggregate principal amount of 5.5% senior notes due June 1, 2024 (the “2024 Senior Notes”).  The 2024 Senior Notes were issued at 100% of the principal amount and require semi-annual interest payments in June and December.  The net proceeds from the issuance of the 2024 Senior Notes, along with cash on hand, were used to repurchase, satisfy and discharge all of the Partnership’s then-outstanding 7.5% senior notes due in 2018.

2025 Senior Notes.  On February 25, 2015, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a public offering of $250,000 in aggregate principal amount of 5.75% senior notes due March 1, 2025 (the “2025 Senior Notes”).  The 2025 Senior Notes were issued at 100% of the principal amount and require semi-annual interest payments in March and September.  The net proceeds from the issuance of the 2025 Senior Notes, along with cash on hand, were used to repurchase, satisfy and discharge all of the Partnership’s then-outstanding 7.375% senior notes due in 2020.  

2027 Senior Notes.  On February 14, 2017, the Partnership and its 100%-owned subsidiary, Suburban Energy Finance Corp., completed a public offering of $350,000 in aggregate principal amount of 5.875% senior notes due March 1, 2027 (the “2027 Senior Notes”).  The 2027 Senior Notes were issued at 100% of the principal amount and require semi-annual interest payments in March and September.  The net proceeds from the issuance of the 2027 Senior Notes, along with borrowings under the Revolving Credit Facility, were used to repurchase, satisfy and discharge all of the previously outstanding 7.375% senior notes due in 2021.

The Partnership’s obligations under the 2024 Senior Notes, 2025 Senior Notes and 2027 Senior Notes (collectively, the “Senior Notes”) are unsecured and rank senior in right of payment to any future subordinated indebtedness and equally in right of payment with any future senior indebtedness.  The Senior Notes are structurally subordinated to, which means they rank effectively behind, any debt and other liabilities of the Operating Partnership.  The Partnership is permitted to redeem some or all of the Senior Notes at redemption prices and times as specified in the indentures governing the Senior Notes.  The Senior Notes each have a change of control provision that would require the Partnership to offer to repurchase the notes at 101% of the principal amount repurchased, if a change of control, as defined in the indenture, occurs and is followed by a rating decline (a decrease in the rating of the notes by either Moody’s Investors Service or Standard and Poor’s Rating Group by one or more gradations) within 90 days of the consummation of the change of control.

Credit Agreement.  The Operating Partnership has an amended and restated credit agreement, dated March 3, 2016 (the “Amended Credit Agreement”) that provides for a five-year $500,000 revolving credit facility (the “Revolving Credit Facility”) with a maturity date of March 3, 2021, of which $151,145 and $162,645 was outstanding as of June 30, 2018 and September 30, 2017, respectively.  Borrowings under the Revolving Credit Facility may be used for general corporate purposes, including working capital, capital expenditures and acquisitions.  The Operating Partnership has the right to prepay any borrowings under the Revolving Credit Facility, in whole or in part, without penalty at any time prior to maturity.

The Amended Credit Agreement contains certain restrictive and affirmative covenants applicable to the Operating Partnership, its subsidiaries and the Partnership, as well as certain financial covenants, including (a) requiring the Partnership’s Consolidated Interest Coverage Ratio, as defined in the Amended Credit Agreement, to be not less than 2.5 to 1.0 as of the end of any fiscal quarter, (b) prohibiting the Total Consolidated Leverage Ratio, as defined in the Amended Credit Agreement, of the Partnership from being greater than 5.95 to 1.0 for each fiscal quarter ending in December 2017, and March and June 2018, 5.75 to 1.0 for the fiscal quarter ending in September 2018, and 5.5 to 1.0 for the fiscal quarter ending in December 2018 and for each fiscal quarter thereafter, and (c) prohibiting the Senior Secured Consolidated Leverage Ratio, as defined in the Amended Credit Agreement, of the Operating Partnership from being greater than 3.0 to 1.0 as of the end of any fiscal quarter.  

The Partnership and certain subsidiaries of the Operating Partnership act as guarantors with respect to the obligations of the Operating Partnership under the Amended Credit Agreement pursuant to the terms and conditions set forth therein.  The obligations under the Amended Credit Agreement are secured by liens on substantially all of the personal property of the Partnership, the Operating Partnership and their subsidiaries, as well as mortgages on certain real property.

Borrowings under the Revolving Credit Facility bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, LIBOR plus the Applicable Rate, or the base rate, defined as the higher of the Federal Funds Rate plus ½ of 1%, the administrative agent bank’s prime rate, or LIBOR plus 1%, plus in each case the Applicable Rate.  The Applicable Rate is dependent upon the Partnership’s Total Consolidated Leverage Ratio.  As of June 30, 2018, the interest rate for borrowings under the Revolving Credit Facility was approximately 4.8%.  The interest rate and the Applicable Rate will be reset following the end of each calendar quarter.

In connection with a previous credit agreement, the Operating Partnership had entered into an interest rate swap agreement with a notional amount of $100,000, an effective date of June 25, 2013 and a termination date of January 5, 2017.  Under this interest rate swap agreement, the Operating Partnership paid a fixed interest rate of 1.63% to the issuing lender on the notional principal amount outstanding, and the issuing lender paid the Operating Partnership a floating rate, namely LIBOR, on the same notional principal amount.  The interest rate swap was designated as a cash flow hedge.  The Partnership did not enter into a new interest rate swap agreement upon termination.

As of June 30, 2018, the Partnership had standby letters of credit issued under the Revolving Credit Facility of $45,226 which expire periodically through April 30, 2019.

The Amended Credit Agreement and the Senior Notes both contain various restrictive and affirmative covenants applicable to the Operating Partnership, its subsidiaries and the Partnership, respectively, including (i) restrictions on the incurrence of additional indebtedness, and (ii) restrictions on certain liens, investments, guarantees, loans, advances, payments, mergers, consolidations, distributions, sales of assets and other transactions.  Under the Amended Credit Agreement and the indentures governing the Senior Notes, the Operating Partnership and the Partnership are generally permitted to make cash distributions equal to available cash, as defined, as of the end of the immediately preceding quarter, if no event of default exists or would exist upon making such distributions, and with respect to the indentures governing the Senior Notes, the Partnership’s Consolidated Fixed Charge Coverage Ratio, as defined, is greater than 1.75 to 1.  The Partnership and the Operating Partnership were in compliance with all covenants and terms of the Senior Notes and the Amended Credit Agreement as of June 30, 2018.

The aggregate amounts of long-term debt maturities subsequent to June 30, 2018 are as follows: fiscal 2018: $-0-; fiscal 2019: $-0-; fiscal 2020: $-0-; fiscal 2021: $151,145; fiscal 2022: $-0-; and thereafter: $1,125,000.

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Distributions of Available Cash

9 Months Ended

Jun. 30, 2018

Distributions Made To Members Or Limited Partners [Abstract]

Distributions of Available Cash

9. Distributions of Available Cash

The Partnership makes distributions to its partners no later than 45 days after the end of each fiscal quarter in an aggregate amount equal to its Available Cash for such quarter. Available Cash, as defined in the Partnership Agreement, generally means all cash on hand at the end of the respective fiscal quarter less the amount of cash reserves established by the Board of Supervisors in its reasonable discretion for future cash requirements. These reserves are retained for the proper conduct of the Partnership’s business, the payment of debt principal and interest and for distributions during the next four quarters.

On July 26, 2018, the Partnership announced a quarterly distribution of $0.60 per Common Unit, or $2.40 per Common Unit on an annualized basis, in respect of the third quarter of fiscal 2018, payable on August 14, 2018 to holders of record on August 7, 2018.

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Unit-Based Compensation Arrangements

9 Months Ended

Jun. 30, 2018

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Unit-Based Compensation Arrangements

10. Unit-Based Compensation Arrangements

The Partnership recognizes compensation cost over the respective service period for employee services received in exchange for an award of equity, or equity-based compensation, based on the grant date fair value of the award.  The Partnership measures liability awards under an equity-based payment arrangement based on remeasurement of the award’s fair value at the conclusion of each interim and annual reporting period until the date of settlement, taking into consideration the probability that the performance conditions will be satisfied.

Restricted Unit Plans.  On July 22, 2009, the Partnership adopted the Suburban Propane Partners, L.P. 2009 Restricted Unit Plan, as amended (the “2009 Restricted Unit Plan”), which authorizes the issuance of Common Units to executives, managers and other employees and members of the Board of Supervisors of the Partnership. The total number of Common Units authorized for issuance under the 2009 Restricted Unit Plan was 2,400,000 as of June 30, 2018.  In accordance with an August 6, 2013 amendment to the 2009 Restricted Unit Plan, unless otherwise stipulated by the Compensation Committee of the Partnership’s Board of Supervisors on or before the grant date, all restricted unit awards granted after the date of the amendment will vest 33.33% on each of the first three anniversaries of the award grant date.  Prior to the August 6, 2013 amendment, unless otherwise stipulated by the Compensation Committee of the Partnership’s Board of Supervisors on or before the grant date, restricted units issued under the 2009 Restricted Unit Plan vest over time with 25% of the Common Units vesting at the end of each of the third and fourth anniversaries of the grant date and the remaining 50% of the Common Units vesting at the end of the fifth anniversary of the grant date.  The 2009 Restricted Unit Plan participants are not eligible to receive quarterly distributions on, or vote, their respective restricted units until vested.  Restricted units cannot be sold or transferred prior to vesting.  The value of the restricted unit is established by the market price of the Common Unit on the date of grant, net of estimated future distributions during the vesting period.  Restricted units are subject to forfeiture in certain circumstances as defined in the 2009 Restricted Unit Plan. Compensation expense for the unvested awards is recognized ratably over the vesting periods and is net of estimated forfeitures.  At the Partnership’s Tri-Annual Meeting held on May 15, 2018, the Unitholders approved the Partnership's 2018 Restricted Unit Plan (the “2018 Restricted Unit Plan” and together with the 2009 Restricted Unit Plan, the “Restricted Unit Plans”) authorizing the issuance of up to 1,800,000 Common Units.  As of June 30, 2018, there were no awards granted under the 2018 Restricted Unit Plan.

During the nine months ended June 30, 2018, the Partnership awarded 424,431 restricted units under the 2009 Restricted Unit Plan at an aggregate grant date fair value of $8,285.  The following is a summary of activity for the 2009 Restricted Unit Plan for the nine months ended June 30, 2018:

				WeightedAverage
	Restricted			Grant Date Fair
	Units			Value Per Unit
Outstanding September 30, 2017		621,045		$	22.10
Awarded		424,431			19.52
Forfeited		(13,992	)		(19.70	)
Vested (with Common Units issued)		(335,253	)		(24.39	)
Outstanding June 30, 2018		696,231		$	19.47

As of June 30, 2018, unrecognized compensation cost related to unvested restricted units awarded under the 2009 Restricted Unit Plan amounted to $4,322.  Compensation cost associated with unvested awards is expected to be recognized over a weighted-average period of one year.  Compensation expense for the 2009 Restricted Unit Plan, net of forfeitures, for the three and nine months ended June 30, 2018 was $1,715 and $6,862, respectively, and $1,372 and $6,209, for the three and nine months ended June 24, 2017, respectively.

Distribution Equivalent Rights Plan.  On January 17, 2017, the Partnership adopted the Distribution Equivalent Rights Plan (the “DER Plan”), which gives the Compensation Committee of the Partnership’s Board of Supervisors discretion to award distribution equivalent rights (“DERs”) to executive officers of the Partnership.  Once awarded, DERs entitle the grantee to a cash payment each time the Board of Supervisors declares a cash distribution on the Partnership’s Common Units, which cash payment will be equal to an amount calculated by multiplying the number of unvested restricted units which are held by the grantee on the record date of the distribution, by the amount of the declared distribution per Common Unit. Compensation expense recognized under the DER Plan for the three and nine months ended June 30, 2018 was $201 and $609, respectively, and $205 and $640 for the three and nine months ended June 24, 2017.

Long-Term Incentive Plan.  On August 6, 2013, the Partnership adopted the 2014 Long-Term Incentive Plan (“LTIP”).  The LTIP is a non-qualified, unfunded, long-term incentive plan for officers and key employees that provides for payment, in the form of cash, of an award of equity-based compensation at the end of a three-year performance period.  The level of compensation earned under the LTIP is based on the Partnership’s average distribution coverage ratio over the three-year measurement period.  The Partnership’s average distribution coverage ratio is calculated as the Partnership’s average distributable cash flow, as defined by the LTIP, for each of the three years in the measurement period, subject to certain adjustments as set forth in the LTIP, divided by the amount of annualized cash distributions to be paid by the Partnership.

As a result of the quarterly remeasurement of the liability for awards under the LTIP, compensation expense for the three and nine months ended June 30, 2018 reflected expense of $595 and $2,719, respectively, and income of $550 and $2,026 for the three and nine months ended June 24, 2017, respectively. As of June 30, 2018 and September 30, 2017, the Partnership had a liability included within accrued employment and benefit costs (or other liabilities, as applicable) of $4,356 and $1,637, respectively, related to estimated future payments under the LTIP.

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Commitments and Contingencies

9 Months Ended

Jun. 30, 2018

Commitments And Contingencies Disclosure [Abstract]

Commitments and Contingencies

11. Commitments and Contingencies

Self-Insurance.  The Partnership is self-insured for general and product, workers’ compensation and automobile liabilities up to predetermined thresholds above which third party insurance applies. As of June 30, 2018 and September 30, 2017, the Partnership had accrued insurance liabilities of $71,303 and $68,581, respectively, representing the total estimated losses under these self-insurance programs. For the portion of the estimated liability that exceeds insurance deductibles, the Partnership records an asset within other assets (or prepaid expenses and other current assets, as applicable) related to the amount of the liability expected to be covered by insurance which amounted to $19,916 and $18,626 as of June 30, 2018 and September 30, 2017.

Legal Matters.  The Partnership’s operations are subject to operating hazards and risks normally incidental to handling, storing and delivering combustible liquids such as propane. The Partnership has been, and will continue to be, a defendant in various legal proceedings and litigation as a result of these operating hazards and risks, and as a result of other aspects of its business. In this regard, the Partnership’s natural gas and electricity business is currently a defendant in two putative class action suits in New York and Pennsylvania. The complaints allege a number of claims regarding pricing to its electricity customers in those states under various consumer statutes and common law. Based on the nature of the allegations under these suits, the Partnership believes that the suits are without merit and is contesting each of these suits vigorously.  With respect to these pending suits, based on the merits of the allegations, a liability for a loss contingency is not required at this time.  Although any litigation is inherently uncertain, based on past experience, the information currently available to the Partnership, and the amount of its accrued insurance liabilities, the Partnership does not believe that currently pending or threatened litigation matters, or known claims or known contingent claims, will have a material adverse effect on its results of operations, financial condition or cash flow.

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Guarantees

9 Months Ended

Jun. 30, 2018

Guarantees [Abstract]

Guarantees

12. Guarantees

The Partnership has residual value guarantees associated with certain of its operating leases, related primarily to transportation equipment, with remaining lease periods scheduled to expire periodically through fiscal 2028.  Upon completion of the lease period, the Partnership guarantees that the fair value of the equipment will equal or exceed the guaranteed amount, or the Partnership will pay the lessor the difference.  Although the fair value of equipment at the end of its lease term has historically exceeded the guaranteed amounts, the maximum potential amount of aggregate future payments the Partnership could be required to make under these leasing arrangements, assuming the equipment is deemed worthless at the end of the lease term, was $16,407 as of June 30, 2018.  The fair value of residual value guarantees for outstanding operating leases was de minimis as of June 30, 2018 and September 30, 2017.

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Pension Plans and Other Postretirement Benefits

9 Months Ended

Jun. 30, 2018

Defined Benefit Pension Plans And Defined Benefit Postretirement Plans Disclosure [Abstract]

Pension Plans and Other Postretirement Benefits

13. Pension Plans and Other Postretirement Benefits

The following table provides the components of net periodic benefit costs:

	Pension Benefits
	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Interest cost	$	944		$	1,041		$	2,832		$	3,123
Expected return on plan assets		(473	)		(537	)		(1,420	)		(1,611	)
Amortization of net loss		920			1,301			2,762			3,901
Net periodic benefit cost	$	1,391		$	1,805		$	4,174		$	5,413

	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Interest cost	$	69		$	96		$	208		$	288
Amortization of prior service credits		(124	)		—			(374	)		—
Amortization of net (gain)		(163	)		(98	)		(491	)		(292	)
Net periodic benefit cost	$	(218	)	$	(2	)	$	(657	)	$	(4	)

The Partnership expects to contribute approximately $4,764 to the defined benefit pension plan during fiscal 2018, of which $3,839 was contributed during the nine months ended June 30, 2018. The projected annual contribution requirements related to the Partnership’s postretirement health care and life insurance benefit plan for fiscal 2018 is $1,243, of which $847 was contributed during the nine months ended June 30, 2018.

The Partnership contributes to multi-employer pension plans (“MEPPs”) in accordance with various collective bargaining agreements covering union employees. As one of the many participating employers in these MEPPs, the Partnership is responsible with the other participating employers for any plan underfunding.  As of June 30, 2018 and September 30, 2017, the Partnership’s estimated obligation to these MEPPs was $22,773 and $23,665, respectively, as a result of its voluntary full withdrawal from certain MEPPs.

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Amounts Reclassified Out of Accumulated Other Comprehensive Income

9 Months Ended

Jun. 30, 2018

Accumulated Other Comprehensive Income Loss Net Of Tax [Abstract]

Amounts Reclassified Out of Accumulated Other Comprehensive Income

14. Amounts Reclassified Out of Accumulated Other Comprehensive Income

The following table summarizes amounts reclassified out of accumulated other comprehensive (loss) income for the three and nine months ended June 30, 2018 and June 24, 2017:

	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Cash Flow Hedges
Balance, beginning of period	$	—		$	—		$	—		$	(205	)
Other comprehensive income before reclassifications:
Unrealized (losses)		—			—			—			(10	)
Reclassifications to earnings:
Realized losses (1)		—			—			—			215
Other comprehensive income		—			—			—			205
Balance, end of period	$	—		$	—		$	—		$	—
Pension Benefits
Balance, beginning of period	$	(35,469	)	$	(48,791	)	$	(37,311	)	$	(51,391	)
Reclassifications to earnings:
Amortization of net loss (2)		920			1,301			2,762			3,901
Other comprehensive income		920			1,301			2,762			3,901
Balance, end of period	$	(34,549	)	$	(47,490	)	$	(34,549	)	$	(47,490	)
Postretirement Benefits
Balance, beginning of period	$	8,171		$	5,570		$	8,499		$	5,764
Reclassifications to earnings:
Amortization of net gain (2)		(163	)		(98	)		(491	)		(292	)
Other comprehensive loss		(163	)		(98	)		(491	)		(292	)
Balance, end of period	$	8,008		$	5,472		$	8,008		$	5,472
Accumulated Other Comprehensive Income (Loss)
Balance, beginning of period	$	(27,298	)	$	(43,221	)	$	(28,812	)	$	(45,832	)
Other comprehensive income before reclassifications		—			—			—			(10	)
Reclassifications to earnings		757			1,203			2,271			3,824
Other comprehensive income		757			1,203			2,271			3,814
Balance, end of period	$	(26,541	)	$	(42,018	)	$	(26,541	)	$	(42,018	)

(1) Reclassification of realized losses on cash flow hedges are recognized in interest expense.

(2) These amounts are included in the computation of net periodic benefit cost.  See Note 13, “Pension Plans and Other Postretirement Benefits.”

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Income Taxes

9 Months Ended

Jun. 30, 2018

Income Tax Disclosure [Abstract]

Income Taxes

15. Income Taxes

For federal income tax purposes, as well as for state income tax purposes in the majority of the states in which the Partnership operates, the earnings attributable to the Partnership and the Operating Partnership are not subject to income tax at the partnership level. With the exception of those states that impose an entity-level income tax on partnerships, the taxable income or loss attributable to the Partnership and to the Operating Partnership, which may vary substantially from the income (loss) before income taxes reported by the Partnership in the condensed consolidated statement of operations, are includable in the federal and state income tax returns of the Common Unitholders. The aggregate difference in the basis of the Partnership’s net assets for financial and tax reporting purposes cannot be readily determined as the Partnership does not have access to each Common Unitholder’s basis in the Partnership.

As described in Note 1, the earnings of the Corporate Entities are subject to corporate level federal and state income tax.  However, based upon past performance, the Corporate Entities are currently reporting an income tax provision composed primarily of minimum state income taxes.  A full valuation allowance has been provided against the deferred tax assets (with the exception of the AMT credit carryforward; see below) based upon an analysis of all available evidence, both negative and positive at the balance sheet date, which, taken as a whole, indicates that it is more likely than not that sufficient future taxable income will not be available to utilize the assets.  Management’s periodic reviews include, among other things, the nature and amount of the taxable income and expense items, the expected timing of when assets will be used or liabilities will be required to be reported and the reliability of historical profitability of businesses expected to provide future earnings. Furthermore, management considered tax-planning strategies it could use to increase the likelihood that the deferred assets will be realized.

On December 22, 2017, the Tax Cuts and Jobs Act (“2017 Act”) was signed into law, which enacted significant changes to U.S. tax and related laws.  Some of the provisions of the 2017 Act that could affect the Partnership, the Operating Partnership and their subsidiaries include, but are not limited to, a reduction of the federal corporate income tax rate from 35% to 21%, limitations on the deductibility of net business interest expense, restrictions on the use of net operating loss carryforwards arising in taxable years beginning after December 31, 2017 and full expensing for certain qualified property.

In the case of a corporation, the 2017 Act made Alternative Minimum Tax (“AMT”) credit carryforwards fully refundable without regard to future taxable income. Accordingly, the Partnership concluded that the existing valuation allowance on the AMT credit carryforwards of the Corporate Entities should be released as part of accounting for tax reform. The reversal of the valuation allowance resulted in a $1,086 discrete deferred tax benefit being recorded during the first quarter of fiscal 2018. The Partnership remeasured all other federal net deferred tax assets of the Corporate Entities using the new 21% federal income tax rate and correspondingly adjusted the full valuation allowance. The blended corporate tax federal rate requirements of Internal Revenue Code Section 15 do not apply because the Corporate Entities are calendar-year tax filers.

The Partnership will continue to analyze the 2017 Act to determine the full effects of the new law on its consolidated financial statements.

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Segment Information

9 Months Ended

Jun. 30, 2018

Segment Reporting [Abstract]

Segment Information

16. Segment Information

The Partnership manages and evaluates its operations in four operating segments, three of which are reportable segments: Propane, Fuel Oil and Refined Fuels, and Natural Gas and Electricity. The chief operating decision maker evaluates performance of the operating segments using a number of performance measures, including gross margins and income before interest expense and provision for income taxes (operating profit). Costs excluded from these profit measures are captured in Corporate and include corporate overhead expenses not allocated to the operating segments. Unallocated corporate overhead expenses include all costs of back office support functions that are reported as general and administrative expenses within the condensed consolidated statements of operations. In addition, certain costs associated with field operations support that are reported in operating expenses within the condensed consolidated statements of operations, including purchasing, training and safety, are not allocated to the individual operating segments. Thus, operating profit for each operating segment includes only the costs that are directly attributable to the operations of the individual segment. The accounting policies of the operating segments are otherwise the same as those described in Note 2, “Summary of Significant Accounting Policies,” in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 30, 2017.

The propane segment is primarily engaged in the retail distribution of propane to residential, commercial, industrial and agricultural customers and, to a lesser extent, wholesale distribution to large industrial end users. In the residential and commercial markets, propane is used primarily for space heating, water heating, cooking and clothes drying. Industrial customers use propane generally as a motor fuel burned in internal combustion engines that power over-the-road vehicles, forklifts and stationary engines, to fire furnaces and as a cutting gas.  In the agricultural markets, propane is primarily used for tobacco curing, crop drying, poultry brooding and weed control.

The fuel oil and refined fuels segment is primarily engaged in the retail distribution of fuel oil, diesel, kerosene and gasoline to residential and commercial customers for use primarily as a source of heat in homes and buildings.

The natural gas and electricity segment is engaged in the marketing of natural gas and electricity to residential and commercial customers in the deregulated energy markets of New York and Pennsylvania. Under this operating segment, the Partnership owns the relationship with the end consumer and has agreements with the local distribution companies to deliver the natural gas or electricity from the Partnership’s suppliers to the customer.

Activities in the “all other” category include the Partnership’s service business, which is primarily engaged in the sale, installation and servicing of a wide variety of home comfort equipment, particularly in the areas of heating and ventilation.

The following table presents certain data by reportable segment and provides a reconciliation of total operating segment information to the corresponding consolidated amounts for the periods presented:

	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Revenues:
Propane	$	205,400		$	188,406		$	990,344		$	843,519
Fuel oil and refined fuels		15,400			12,886			82,414			69,612
Natural gas and electricity		10,403			11,923			43,942			44,229
All other		10,733			9,680			34,795			33,420
Total revenues	$	241,936		$	222,895		$	1,151,495		$	990,780
Operating income (loss):
Propane (1)	$	28,073		$	11,323		$	245,845		$	201,332
Fuel oil and refined fuels		(891	)		199			10,132			9,875
Natural gas and electricity		2,192			2,806			11,131			11,461
All other		(4,607	)		(5,747	)		(14,821	)		(16,139	)
Corporate		(21,706	)		(19,643	)		(67,248	)		(61,249	)
Total operating income (loss)		3,061			(11,062	)		185,039			145,280
Reconciliation to net (loss) income:
Loss on debt extinguishment		—			—			—			1,567
Interest expense, net		19,512			18,502			58,428			54,820
Provision for (benefit from) income taxes		144			152			(749	)		308
Net (loss) income	$	(16,595	)	$	(29,716	)	$	127,360		$	88,585
Depreciation and amortization:
Propane	$	27,875		$	27,787		$	83,944		$	83,243
Fuel oil and refined fuels		571			625			1,866			1,923
Natural gas and electricity		—			—			—			—
All other		57			76			163			222
Corporate		2,756			3,337			8,620			10,368
Total depreciation and amortization	$	31,259		$	31,825		$	94,593		$	95,756

	As of
	June 30,		September30,
	2018		2017
Assets:
Propane	$	2,020,928	$	2,066,997
Fuel oil and refined fuels		49,525		49,863
Natural gas and electricity		12,679		12,455
All other		3,576		2,147
Corporate		44,825		39,821
Total assets	$	2,131,533	$	2,171,283

(1) Includes the loss on sale of business of $4,823 for the nine months ended June 30, 2018 (see Note 3).

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Basis of Presentation (Policies)

9 Months Ended

Jun. 30, 2018

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Principles of Consolidation

Principles of Consolidation.  The condensed consolidated financial statements include the accounts of the Partnership, the Operating Partnership and all of its direct and indirect subsidiaries.  All significant intercompany transactions and account balances have been eliminated.  The Partnership consolidates the results of operations, financial condition and cash flows of the Operating Partnership as a result of the Partnership’s 100% limited partner interest in the Operating Partnership.

The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”).  They include all adjustments that the Partnership considers necessary for a fair statement of the results of operations, financial position and cash flows for the interim periods presented.  Such adjustments consist only of normal recurring items, unless otherwise disclosed.  These financial statements should be read in conjunction with the financial statements included in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 30, 2017.  Due to the seasonal nature of the Partnership’s operations, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.

Fiscal Period

Fiscal Period.  The Partnership uses a 52/53 week fiscal year which ends on the last Saturday in September.  The Partnership’s fiscal quarters are generally thirteen weeks in duration.  When the Partnership’s fiscal year is 53 weeks long, as was the case for fiscal 2017, the corresponding fourth quarter is fourteen weeks in duration.

Revenue Recognition

Revenue Recognition.  Sales of propane, fuel oil and refined fuels are recognized at the time product is delivered to the customer.  Revenue from the sale of appliances and equipment is recognized at the time of sale or when installation is complete, as applicable.  Revenue from repairs, maintenance and other service activities is recognized upon completion of the service.  Revenue from annually billed service contracts is recognized ratably over the service period.  Revenue from the natural gas and electricity business is recognized based on customer usage as determined by meter readings for amounts delivered, some of which may be unbilled at the end of each accounting period.  Revenue from annually billed tank fees is deferred at the time of billings and recognized on a straight-line basis over one year.

Fair Value Measurements

Fair Value Measurements.  The Partnership measures certain of its assets and liabilities at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants – in either the principal market or the most advantageous market.  The principal market is the market with the greatest level of activity and volume for the asset or liability.

The common framework for measuring fair value utilizes a three-level hierarchy to prioritize the inputs used in the valuation techniques to derive fair values.  The basis for fair value measurements for each level within the hierarchy is described below with Level 1 having the highest priority and Level 3 having the lowest.

• Level 1: Quoted prices in active markets for identical assets or liabilities.

• Level 2: Quoted prices in active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations in which all significant inputs are observable in active markets.

• Level 3: Valuations derived from valuation techniques in which one or more significant inputs are unobservable.

Business Combinations

Business Combinations.  The Partnership accounts for business combinations using the acquisition method and accordingly, the assets and liabilities of the acquired entities are recorded at their estimated fair values at the acquisition date.  Goodwill represents the excess of the purchase price over the fair value of the net assets acquired, including the amount assigned to identifiable intangible assets.  The primary drivers that generate goodwill are the value of synergies between the acquired entities and the Partnership, and the acquired assembled workforce, neither of which qualifies as an identifiable intangible asset.  Identifiable intangible assets with finite lives are amortized over their useful lives.  The results of operations of acquired businesses are included in the consolidated financial statements from the acquisition date.  The Partnership expenses all acquisition-related costs as incurred.

Use of Estimates

Use of Estimates.  The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“US GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period.  Estimates have been made by management in the areas of self-insurance and litigation reserves, pension and other postretirement benefit liabilities and costs, valuation of derivative instruments, depreciation and amortization of long-lived assets, asset impairment assessments, tax valuation allowances, allowances for doubtful accounts, and purchase price allocation for acquired businesses.  The Partnership uses Society of Actuaries life expectancy information when developing the annual mortality assumptions for the pension and postretirement benefit plans, which are used to measure net periodic benefit costs and the obligation under these plans.  Actual results could differ from those estimates, making it reasonably possible that a material change in these estimates could occur in the near term.

Reclassifications

Reclassifications.  Certain prior period amounts have been reclassified to conform with the current period presentation.  See Recently Adopted Accounting Pronouncements, below.

Recently Issued and Adopted Accounting Pronouncements

Recently Issued Accounting Pronouncements.  In March 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” (“ASU 2017-07”).  This update provides guidance on the capitalization, presentation and disclosure of net benefit costs.  ASU 2017-07 is effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019 and will be applied retrospectively upon adoption.  The Partnership is currently evaluating the impact that the standard will have on the Partnership’s consolidated statements of operations.

In January 2017, the FASB issued ASU 2017-04, “Simplifying the Test for Goodwill Impairment” (“ASU 2017-04”).  This update eliminates the second of the two-step goodwill impairment test, as described in Note 6, “Goodwill and Other Intangible Assets.”  Instead, an entity should perform its annual or interim goodwill impairment test by comparing the fair value of a reporting unit to its carrying amount and recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value, not to exceed the total amount of goodwill allocated to the reporting unit.  ASU 2017-04 is effective for the first interim period within annual reporting periods beginning after December 15, 2019, which will be the Partnership’s first quarter of fiscal 2021.  Early adoption of ASU 2017-04 is permitted.  The Partnership does not expect that the adoption of ASU 2017-04 will have a material impact on the Partnership’s consolidated financial statements.

In August 2016, the FASB issued ASU 2016-15, “Classification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”).  This update addresses eight specific cash flow issues and is intended to reduce diversity in practice on how certain cash receipts and cash payments are presented and classified in the statement of cash flows.  ASU 2016-15 is effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019.  Early adoption of ASU 2016-15 is permitted.  The Partnership is currently evaluating the impact of adopting the standard on the Partnership’s consolidated statements of cash flows.

In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”). The standard amends the existing accounting standards for lease accounting, including requiring lessees to recognize most leases on their balance sheets and making targeted changes to lessor accounting. ASU 2016-02 is effective for the first interim period within annual reporting periods beginning after December 15, 2018, which will be the Partnership’s first quarter of fiscal 2020.  Early adoption of ASU 2016-02 is permitted. The new leases standard requires a modified retrospective transition approach for all leases existing at, or entered into after, the date of initial application, with an option to use certain transition relief. The Partnership is currently evaluating the impact of adopting ASU 2016-02 on the Partnership’s consolidated financial statements.

In May 2014, the FASB issued ASU 2014-09 “Revenue from Contracts with Customers” (“ASU 2014-09”).  This update provides a principles-based approach to revenue recognition, requiring revenue recognition to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.  The ASU provides a five-step model to be applied to all contracts with customers. The five steps are to identify the contract(s) with the customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract and recognize revenue when each performance obligation is satisfied. On July 9, 2015, the FASB finalized a one-year deferral of the effective date of ASU 2014-09.  The revenue standard is therefore effective for the first interim period within annual reporting periods beginning after December 15, 2017, which will be the Partnership’s first quarter of fiscal 2019.  Early adoption as of the original effective date is permitted.  ASU 2014-09 can be applied either retrospectively to each prior reporting period presented or with the cumulative effect of initially applying the update recognized at the date of the initial application along with additional disclosures.  While the Partnership is still in the process of evaluating the potential impact of ASU 2014-09, it does not expect its adoption will have a material impact on the Partnership’s consolidated financial statements.

Recently Adopted Accounting Pronouncements.During the first quarter of fiscal 2018, the Partnership adopted new accounting guidance regarding stock-based compensation under ASU 2016-09, “Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”).  Cash payments made to the taxing authorities on employees’ behalf for withheld shares are now presented as financing activities on the condensed consolidated statement of cash flows, rather than operating activities.  The amounts paid to federal and state taxing authorities were $847 and $736 for the nine months ended June 30, 2018 and June 24, 2017, respectively.

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Financial Instruments and Risk Management (Tables)

9 Months Ended

Jun. 30, 2018

Fair Value Disclosures [Abstract]

Fair value of the Partnership's derivative instruments and their location in the condensed consolidated balance sheets

The following summarizes the fair value of the Partnership’s derivative instruments and their location in the condensed consolidated balance sheets as of June 30, 2018 and September 30, 2017, respectively:

	As of June 30, 2018			As of September 30, 2017
Asset Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity-related derivatives	Other current assets	$	10,953	Other current assets	$	11,164
	Other assets		158	Other assets		771
		$	11,111		$	11,935
Liability Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity-related derivatives	Other current liabilities	$	4,962	Other current liabilities	$	1,978
	Other liabilities		—	Other liabilities		432
		$	4,962		$	2,410

Reconciliation of the beginning and ending balances of assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs

The following summarizes the reconciliation of the beginning and ending balances of assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs:

	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)
	Nine Months Ended						Nine Months Ended
	June 30, 2018						June 24, 2017
	Assets			Liabilities			Assets			Liabilities
Beginning balance of over-the-counter options	$	4,108		$	737		$	809		$	—
Beginning balance realized during the period		(3,277	)		(737	)		(589	)		—
Contracts purchased during the period		1,352			158			—			—
Change in the fair value of outstanding contracts		(800	)		—			(115	)		—
Ending balance of over-the-counter options	$	1,383		$	158		$	105		$	—

Effect of the Partnership's derivative instruments on the condensed consolidated statements of operations

The effect of the Partnership’s derivative instruments on the condensed consolidated statements of operations and the condensed consolidated statements of comprehensive income, as applicable, for the three and nine months ended June 30, 2018 and June 24, 2017 are as follows:

	Three Months Ended June 30, 2018					Three Months Ended June 24, 2017
Derivatives in Cash Flow	Gains (Losses) Recognized  in OCI		Gains (Losses) Reclassified from Accumulated OCI into Income			Gains (Losses) Recognized  in OCI		Gains (Losses) Reclassified from Accumulated OCI into Income
Hedging Relationships	(Effective Portion)		Location	Amount		(Effective Portion)		Location	Amount
Interest rate swap	$	—	Interest expense	$	—	$	—	Interest expense	$	—
Derivatives Not Designated as Hedging Instruments			Unrealized Gains (Losses) Recognized in Income					Unrealized Gains (Losses) Recognized in Income
			Location	Amount				Location	Amount
Commodity-related    derivatives			Cost of products sold	$	3,806			Cost of products sold	$	(655	)

Nine Months Ended June 30, 2018

Nine Months Ended June 24, 2017

Derivatives in Cash Flow

Gains (Losses) Recognized  in OCI

Gains (Losses) Reclassified from Accumulated OCI into Income

Gains (Losses) Recognized  in OCI

Gains (Losses) Reclassified from Accumulated OCI into Income

Hedging Relationships

(Effective Portion)

Location

Amount

(Effective Portion)

Location

Amount

Interest rate swap

$

—

Interest expense

$

—

$

(10

)

Interest expense

$

(215

)

Derivatives Not Designated as Hedging Instruments

Unrealized Gains (Losses) Recognized in Income

Unrealized Gains (Losses) Recognized in Income

Location

Amount

Location

Amount

Commodity-related    derivatives

Cost of products sold

$

(1,421

)

Cost of products sold

$

(2,708

)

Fair value of the Partnership's recognized derivative assets and liabilities on a gross basis and amounts offset on the condensed consolidated balance sheets

The following table presents the fair value of the Partnership’s recognized derivative assets and liabilities on a gross basis and amounts offset on the condensed consolidated balance sheets subject to enforceable master netting arrangements or similar agreements:

	As of June 30, 2018							As of September 30, 2017
						Net amounts							Net amounts
						presented in the							presented in the
	Gross amounts		Effects of netting			balance sheet		Gross amounts		Effects of netting			balance sheet
Asset Derivatives
Commodity-related derivatives	$	19,688	$	(8,577	)	$	11,111	$	16,378	$	(4,443	)	$	11,935
Liability Derivatives
Commodity-related derivatives	$	13,539	$	(8,577	)	$	4,962	$	6,853	$	(4,443	)	$	2,410

Fair Value of the Partnership's Senior Notes

Based upon quoted market prices (a Level 1 input), the fair value of the Senior Notes (also defined below in Note 8) of the Partnership are as follows:

	As of
	June 30,		September 30,
	2018		2017
5.5% senior notes due June 1, 2024	$	511,875	$	527,888
5.75% senior notes due March 1, 2025		240,625		248,750
5.875% senior notes due March 1, 2027		327,250		349,125
	$	1,079,750	$	1,125,763

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Inventories (Tables)

9 Months Ended

Jun. 30, 2018

Inventory Disclosure [Abstract]

Inventories

Inventories consist of the following:

	As of
	June 30,		September 30,
	2018		2017
Propane, fuel oil and refined fuels and natural gas	$	48,210	$	51,844
Appliances		1,628		1,376
	$	49,838	$	53,220

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Goodwill and Other Intangible Assets (Tables)

9 Months Ended

Jun. 30, 2018

Goodwill And Intangible Assets Disclosure [Abstract]

Carrying values of goodwill assigned to the partnership's operating segments

The carrying values of goodwill assigned to the Partnership’s operating segments are as follows:

				Fuel oil and			Natural gas
	Propane			refined fuels			and electricity		Total
Balance as of September 30, 2017
Goodwill	$	1,082,297		$	10,900		$	7,900	$	1,101,097
Accumulated adjustments		—			(6,462	)		—		(6,462	)
	$	1,082,297		$	4,438		$	7,900	$	1,094,635
Fiscal 2018 Activity
Goodwill disposed (2)	$	(1,165	)	$	—		$	—	$	(1,165	)
Balance as of June 30, 2018
Goodwill	$	1,081,132		$	10,900		$	7,900	$	1,099,932
Accumulated adjustments		—			(6,462	)		—		(6,462	)
	$	1,081,132		$	4,438		$	7,900	$	1,093,470

Other intangible assets

Other intangible assets consist of the following:

	As of
	June 30,			September 30,
	2018			2017
Customer relationships (1) (2)	$	499,433		$	492,656
Non-compete agreements (1)		33,540			31,040
Other		1,967			1,967
		534,940			525,663
Less: accumulated amortization
Customer relationships		(317,024	)		(279,287	)
Non-compete agreements		(27,207	)		(25,242	)
Other		(1,327	)		(1,258	)
		(345,558	)		(305,787	)
	$	189,382		$	219,876

(1) Reflects the impact from the acquisitions (Note 3).

(2) Reflects the impact from the disposition of certain assets and operations in a non-strategic market of the propane

segment (Note 3).

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Long-Term Borrowings (Tables)

9 Months Ended

Jun. 30, 2018

Debt Disclosure [Abstract]

Long-term borrowings

Long-term borrowings consist of the following:

	As of
	June 30,			September 30,
	2018			2017
5.5% senior notes, due June 1, 2024	$	525,000		$	525,000
5.75% senior notes, due March 1, 2025		250,000			250,000
5.875% senior notes due March 1, 2027		350,000			350,000
Revolving Credit Facility, due March 3, 2021		151,145			162,645
Subtotal		1,276,145			1,287,645
Less: unamortized debt issuance costs		(13,967	)		(15,481	)
	$	1,262,178		$	1,272,164

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Unit-Based Compensation Arrangements (Tables)

9 Months Ended

Jun. 30, 2018

2009 Restricted Unit Plan [Member]

Summary of activity for the Restricted Unit Plans

The following is a summary of activity for the 2009 Restricted Unit Plan for the nine months ended June 30, 2018:

				WeightedAverage
	Restricted			Grant Date Fair
	Units			Value Per Unit
Outstanding September 30, 2017		621,045		$	22.10
Awarded		424,431			19.52
Forfeited		(13,992	)		(19.70	)
Vested (with Common Units issued)		(335,253	)		(24.39	)
Outstanding June 30, 2018		696,231		$	19.47

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Pension Plans and Other Postretirement Benefits (Tables)

9 Months Ended

Jun. 30, 2018

Defined Benefit Pension Plans And Defined Benefit Postretirement Plans Disclosure [Abstract]

Components of Net Periodic Benefit Costs

The following table provides the components of net periodic benefit costs:

	Pension Benefits
	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Interest cost	$	944		$	1,041		$	2,832		$	3,123
Expected return on plan assets		(473	)		(537	)		(1,420	)		(1,611	)
Amortization of net loss		920			1,301			2,762			3,901
Net periodic benefit cost	$	1,391		$	1,805		$	4,174		$	5,413

	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Interest cost	$	69		$	96		$	208		$	288
Amortization of prior service credits		(124	)		—			(374	)		—
Amortization of net (gain)		(163	)		(98	)		(491	)		(292	)
Net periodic benefit cost	$	(218	)	$	(2	)	$	(657	)	$	(4	)

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Amounts Reclassified Out of Accumulated Other Comprehensive Income (Tables)

9 Months Ended

Jun. 30, 2018

Accumulated Other Comprehensive Income Loss Net Of Tax [Abstract]

Reclassification out of accumulated other comprehensive (loss) income

The following table summarizes amounts reclassified out of accumulated other comprehensive (loss) income for the three and nine months ended June 30, 2018 and June 24, 2017:

	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Cash Flow Hedges
Balance, beginning of period	$	—		$	—		$	—		$	(205	)
Other comprehensive income before reclassifications:
Unrealized (losses)		—			—			—			(10	)
Reclassifications to earnings:
Realized losses (1)		—			—			—			215
Other comprehensive income		—			—			—			205
Balance, end of period	$	—		$	—		$	—		$	—
Pension Benefits
Balance, beginning of period	$	(35,469	)	$	(48,791	)	$	(37,311	)	$	(51,391	)
Reclassifications to earnings:
Amortization of net loss (2)		920			1,301			2,762			3,901
Other comprehensive income		920			1,301			2,762			3,901
Balance, end of period	$	(34,549	)	$	(47,490	)	$	(34,549	)	$	(47,490	)
Postretirement Benefits
Balance, beginning of period	$	8,171		$	5,570		$	8,499		$	5,764
Reclassifications to earnings:
Amortization of net gain (2)		(163	)		(98	)		(491	)		(292	)
Other comprehensive loss		(163	)		(98	)		(491	)		(292	)
Balance, end of period	$	8,008		$	5,472		$	8,008		$	5,472
Accumulated Other Comprehensive Income (Loss)
Balance, beginning of period	$	(27,298	)	$	(43,221	)	$	(28,812	)	$	(45,832	)
Other comprehensive income before reclassifications		—			—			—			(10	)
Reclassifications to earnings		757			1,203			2,271			3,824
Other comprehensive income		757			1,203			2,271			3,814
Balance, end of period	$	(26,541	)	$	(42,018	)	$	(26,541	)	$	(42,018	)

(1) Reclassification of realized losses on cash flow hedges are recognized in interest expense.

(2) These amounts are included in the computation of net periodic benefit cost.  See Note 13, “Pension Plans and Other Postretirement Benefits.”

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Segment Information (Tables)

9 Months Ended

Jun. 30, 2018

Segment Reporting [Abstract]

Disclosure by reportable segment and reconciliation of total operating segment information

The following table presents certain data by reportable segment and provides a reconciliation of total operating segment information to the corresponding consolidated amounts for the periods presented:

	Three Months Ended						Nine Months Ended
	June 30,			June 24,			June 30,			June 24,
	2018			2017			2018			2017
Revenues:
Propane	$	205,400		$	188,406		$	990,344		$	843,519
Fuel oil and refined fuels		15,400			12,886			82,414			69,612
Natural gas and electricity		10,403			11,923			43,942			44,229
All other		10,733			9,680			34,795			33,420
Total revenues	$	241,936		$	222,895		$	1,151,495		$	990,780
Operating income (loss):
Propane (1)	$	28,073		$	11,323		$	245,845		$	201,332
Fuel oil and refined fuels		(891	)		199			10,132			9,875
Natural gas and electricity		2,192			2,806			11,131			11,461
All other		(4,607	)		(5,747	)		(14,821	)		(16,139	)
Corporate		(21,706	)		(19,643	)		(67,248	)		(61,249	)
Total operating income (loss)		3,061			(11,062	)		185,039			145,280
Reconciliation to net (loss) income:
Loss on debt extinguishment		—			—			—			1,567
Interest expense, net		19,512			18,502			58,428			54,820
Provision for (benefit from) income taxes		144			152			(749	)		308
Net (loss) income	$	(16,595	)	$	(29,716	)	$	127,360		$	88,585
Depreciation and amortization:
Propane	$	27,875		$	27,787		$	83,944		$	83,243
Fuel oil and refined fuels		571			625			1,866			1,923
Natural gas and electricity		—			—			—			—
All other		57			76			163			222
Corporate		2,756			3,337			8,620			10,368
Total depreciation and amortization	$	31,259		$	31,825		$	94,593		$	95,756

	As of
	June 30,		September30,
	2018		2017
Assets:
Propane	$	2,020,928	$	2,066,997
Fuel oil and refined fuels		49,525		49,863
Natural gas and electricity		12,679		12,455
All other		3,576		2,147
Corporate		44,825		39,821
Total assets	$	2,131,533	$	2,171,283

(1) Includes the loss on sale of business of $4,823 for the nine months ended June 30, 2018 (see Note 3).

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Partnership Organization and Formation - Additional Information (Details) - shares	Jun. 30, 2018	Sep. 30, 2017
Consolidation Less Than Wholly Owned Subsidiary Parent Ownership Interest Effects Of Changes Net [Line Items]
Common units outstanding (in units)	61,405,409	61,105,000
Ownership interest in Suburban Energy Finance Corp (in hundredths)	100.00%
General Partner [Member] | Common Unitholders [Member]
Consolidation Less Than Wholly Owned Subsidiary Parent Ownership Interest Effects Of Changes Net [Line Items]
Common units outstanding (in units)	784

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Basis of Presentation - Additional Information (Details) $ in Thousands	9 Months Ended
	Jun. 30, 2018 USD ($) wk	Jun. 24, 2017 USD ($)
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Limited partner interest in the Operating Partnership (in hundredths)	100.00%
Minimum number of weeks in the fiscal year reporting calendar	52
Maximum number of weeks in the fiscal year reporting calendar	53
Minimum number of weeks in a fiscal quarter	13
Maximum number of weeks in a fiscal quarter	14
Cash paid to taxing authorities on employee’s’ behalf for withheld shares | $	$ 847	$ 736

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Acquisition and Disposition of Businesses - Additional Information (Details) $ in Thousands				3 Months Ended		8 Months Ended	9 Months Ended
	Apr. 05, 2018 USD ($)	Dec. 08, 2017 USD ($)	Nov. 07, 2017 USD ($)	Jun. 30, 2018 USD ($)	Dec. 30, 2017 USD ($)	Jun. 30, 2018 USD ($)	Jun. 30, 2018 USD ($)	Jun. 24, 2017 USD ($)
Business Acquisition And Dispositions [Line Items]
Business acquisition, cost of acquired, cash paid	$ 11,900		$ 4,871
Cash paid to acquire business				$ 10,622		$ 4,251	$ 14,873	$ 0
Business disposition, sales price		$ 2,800
Loss on sale of certain assets and operations					$ 4,823		$ 4,823	$ 0
Number of propane assets and operations acquired	2
Non-compete Agreements [Member]
Business Acquisition And Dispositions [Line Items]
Business acquisition, cost of acquired, cash paid	$ 1,750		$ 750

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Financial Instruments and Risk Management - Additional Information (Details) - USD ($)	9 Months Ended	12 Months Ended
	Jun. 30, 2018	Sep. 30, 2017
Derivatives, Fair Value [Line Items]
Maximum maturity period of highly liquid investment considered as cash equivalents	3 months
Margin over basis rate (in hundredths)	1.00%
Cash collateral	$ 0	$ 0
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Weighted average maturity of outstanding commodity-related derivatives	4 months	5 months

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Financial Instruments and Risk Management - Fair Value of the Partnership's Derivative Instruments and their Location in the Condensed Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Commodity-Related Derivatives [Member]
Derivatives, Fair Value [Line Items]
Fair value - assets	$ 19,688	$ 16,378
Fair value - liabilities	13,539	6,853
Derivatives Not Designated as Hedging Instruments [Member]
Derivatives, Fair Value [Line Items]
Fair value - assets	11,111	11,935
Fair value - liabilities	4,962	2,410
Derivatives Not Designated as Hedging Instruments [Member] | Commodity-Related Derivatives [Member] | Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Fair value - assets	10,953	11,164
Derivatives Not Designated as Hedging Instruments [Member] | Commodity-Related Derivatives [Member] | Other Assets [Member]
Derivatives, Fair Value [Line Items]
Fair value - assets	158	771
Derivatives Not Designated as Hedging Instruments [Member] | Commodity-Related Derivatives [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Fair value - liabilities	4,962	1,978
Derivatives Not Designated as Hedging Instruments [Member] | Commodity-Related Derivatives [Member] | Other Liabilities [Member]
Derivatives, Fair Value [Line Items]
Fair value - liabilities	$ 0	$ 432

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Financial Instruments and Risk Management - Reconciliation of the Beginning and Ending Balances of Assets and Liabilities Measured at Fair Value on a Recurring Basis Using Significant Unobservable Inputs (Details) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2018	Jun. 24, 2017
Reconciliation of beginning and ending balances of assets measured at fair value on recurring basis using significant unobservable inputs [Rollforward]
Beginning balance of over-the-counter options	$ 4,108	$ 809
Beginning balance realized during the period	(3,277)	(589)
Contracts purchased during the period	1,352	0
Change in the fair value of outstanding contracts	(800)	(115)
Ending balance of over-the-counter options	1,383	105
Reconciliation of beginning and ending balances of liabilities measured at fair value on recurring basis using significant unobservable inputs [Rollforward]
Beginning balance of over-the-counter options	737	0
Beginning balance realized during the period	(737)	0
Contracts purchased during the period	158	0
Change in the fair value of outstanding contracts	0	0
Ending balance of over-the-counter options	$ 158	$ 0

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Financial Instruments and Risk Management - Effect of the Partnership's Derivative Instruments on the Condensed Consolidated Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 24, 2017	Jun. 30, 2018	Jun. 24, 2017
Interest Rate Swaps [Member] | Derivatives Designated as Hedging Instruments [Member]
Derivative Instruments Gain Loss [Line Items]
Gains (Losses) Recognized in OCI (Effective Portion)	$ 0	$ 0	$ 0	$ (10)
Interest Rate Swaps [Member] | Derivatives Designated as Hedging Instruments [Member] | Interest Expense [Member]
Derivative Instruments Gain Loss [Line Items]
Gains (Losses) Reclassified from Accumulated OCI into Income	0	0	0	(215)
Commodity-Related Derivatives [Member] | Derivatives Not Designated as Hedging Instruments [Member] | Cost of Products Sold [Member]
Derivative Instruments Gain Loss [Line Items]
Unrealized Gains (Losses) Recognized in Income	$ 3,806	$ (655)	$ (1,421)	$ (2,708)

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Financial Instruments and Risk Management - Fair Value of Partnership's Recognized Derivative Assets and Liabilities on a Gross Basis and Amounts Offset on Condensed Consolidated Balance Sheets (Details) - Commodity-Related Derivatives [Member] - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Asset Derivatives [Abstracts]
Gross amounts	$ 19,688	$ 16,378
Effects of netting	(8,577)	(4,443)
Net amounts presented in the balance sheet	11,111	11,935
Liability Derivatives [Abstracts]
Gross amounts	13,539	6,853
Effects of netting	(8,577)	(4,443)
Net amounts presented in the balance sheet	$ 4,962	$ 2,410

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Financial Instruments and Risk Management - Fair Value of the Partnership's Senior Notes (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Bank Debt and Senior Notes [Abstract]
Fair value of Senior Notes	$ 1,079,750	$ 1,125,763
5.5% Senior Notes due June 1, 2024 [Member]
Bank Debt and Senior Notes [Abstract]
Fair value of Senior Notes	511,875	527,888
5.75% Senior Notes due March 1, 2025 [Member]
Bank Debt and Senior Notes [Abstract]
Fair value of Senior Notes	240,625	248,750
5.875% Senior Notes due March 1, 2027 [Member]
Bank Debt and Senior Notes [Abstract]
Fair value of Senior Notes	$ 327,250	$ 349,125

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Financial Instruments and Risk Management - Fair Value of the Partnership's Senior Notes (Parenthetical) (Details)	9 Months Ended
	Jun. 30, 2018	Sep. 30, 2017
5.5% Senior Notes due June 1, 2024 [Member]
Bank Debt and Senior Notes [Abstract]
Stated interest rate (in hundredths)	5.50%	5.50%
Maturity date	Jun. 01, 2024
5.75% Senior Notes due March 1, 2025 [Member]
Bank Debt and Senior Notes [Abstract]
Stated interest rate (in hundredths)	5.75%	5.75%
Maturity date	Mar. 01, 2025
5.875% Senior Notes due March 1, 2027 [Member]
Bank Debt and Senior Notes [Abstract]
Stated interest rate (in hundredths)	5.875%	5.875%
Maturity date	Mar. 01, 2027

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Inventories - Inventories (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Inventory Net [Abstract]
Propane, fuel oil and refined fuels and natural gas	$ 48,210	$ 51,844
Appliances	1,628	1,376
Total inventory	$ 49,838	$ 53,220

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Goodwill and Other Intangible Assets - Additional Information (Details)	9 Months Ended
	Jun. 30, 2018
Goodwill And Intangible Assets Disclosure [Abstract]
Projection period for discounted cash flow analyses to estimate reporting unit fair value	10 years

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Goodwill and Other Intangible Assets - Carrying Values of Goodwill Assigned to Partnership's Operating Segments (Details) - USD ($) $ in Thousands		9 Months Ended
		Jun. 30, 2018	Sep. 30, 2017
Goodwill [Line Items]
Goodwill		$ 1,099,932	$ 1,101,097
Accumulated adjustments		(6,462)	(6,462)
Goodwill, net		1,093,470	1,094,635
Goodwill disposed	[1]	(1,165)
Propane [Member]
Goodwill [Line Items]
Goodwill		1,081,132	1,082,297
Accumulated adjustments		0	0
Goodwill, net		1,081,132	1,082,297
Goodwill disposed	[1]	(1,165)
Fuel Oil and Refined Fuels [Member]
Goodwill [Line Items]
Goodwill		10,900	10,900
Accumulated adjustments		(6,462)	(6,462)
Goodwill, net		4,438	4,438
Goodwill disposed	[1]	0
Natural Gas and Electricity [Member]
Goodwill [Line Items]
Goodwill		7,900	7,900
Accumulated adjustments		0	0
Goodwill, net		7,900	$ 7,900
Goodwill disposed	[1]	$ 0

[1] Reflects the impact from the disposition of certain assets and operations in a non-strategic market of the propane segment (Note 3).

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Goodwill and Other Intangible Assets - Summary of Other Intangible Assets (Details) - USD ($) $ in Thousands		Jun. 30, 2018	Sep. 30, 2017
Finite Lived Intangible Assets [Line Items]
Other intangible assets, gross		$ 534,940	$ 525,663
Accumulated amortization		(345,558)	(305,787)
Other intangible assets, net		189,382	219,876
Customer Relationships [Member]
Finite Lived Intangible Assets [Line Items]
Other intangible assets, gross	[1],[2]	499,433	492,656
Accumulated amortization		(317,024)	(279,287)
Non-compete Agreements [Member]
Finite Lived Intangible Assets [Line Items]
Other intangible assets, gross	[1]	33,540	31,040
Accumulated amortization		(27,207)	(25,242)
Other [Member]
Finite Lived Intangible Assets [Line Items]
Other intangible assets, gross		1,967	1,967
Accumulated amortization		$ (1,327)	$ (1,258)

[1] Reflects the impact from the acquisitions (Note 3).

[2] Reflects the impact from the disposition of certain assets and operations in a non-strategic market of the propane segment (Note 3).

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Net Income Per Common Unit - Additional Information (Details) - shares	9 Months Ended
	Jun. 30, 2018	Jun. 24, 2017
Earnings Per Share [Abstract]
Increase in weighted average units outstanding used to compute basic net income per Common Unit to reflect the potential dilutive effect of the unvested restricted units outstanding (in units)	237,697	183,752

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Long-Term Borrowings - Summary of Long-Term Borrowings (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Debt Instrument [Line Items]
Long-term borrowings	$ 1,276,145	$ 1,287,645
Less: unamortized debt issuance costs	(13,967)	(15,481)
Long-term borrowings	1,262,178	1,272,164
5.5% Senior Notes due June 1, 2024 [Member]
Debt Instrument [Line Items]
Long-term borrowings	525,000	525,000
5.75% Senior Notes due March 1, 2025 [Member]
Debt Instrument [Line Items]
Long-term borrowings	250,000	250,000
5.875% Senior Notes due March 1, 2027 [Member]
Debt Instrument [Line Items]
Long-term borrowings	350,000	350,000
Revolving Credit Facility due March 3, 2021 [Member]
Debt Instrument [Line Items]
Long-term borrowings	$ 151,145	$ 162,645

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Long-Term Borrowings - Summary of Long-Term Borrowings (Parenthetical) (Details)	9 Months Ended
	Jun. 30, 2018	Sep. 30, 2017
5.5% Senior Notes due June 1, 2024 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)	5.50%	5.50%
Maturity date	Jun. 01, 2024
5.75% Senior Notes due March 1, 2025 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)	5.75%	5.75%
Maturity date	Mar. 01, 2025
5.875% Senior Notes due March 1, 2027 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)	5.875%	5.875%
Maturity date	Mar. 01, 2027
Revolving Credit Facility due March 3, 2021 [Member]
Debt Instrument [Line Items]
Maturity date	Mar. 03, 2021

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Long-Term Borrowings - Additional Information (Details)		3 Months Ended					9 Months Ended
	Mar. 03, 2016 USD ($)	Dec. 29, 2018	Sep. 29, 2018	Jun. 30, 2018 USD ($)	Mar. 31, 2018	Dec. 30, 2017	Jun. 30, 2018 USD ($)	Sep. 30, 2017 USD ($)
Debt Instrument [Line Items]
Long-term borrowings				$ 1,262,178,000			$ 1,262,178,000	$ 1,272,164,000
Margin over basis rate (in hundredths)							1.00%
Notional Amount				100,000,000			$ 100,000,000
Consolidated fixed charge coverage ratio, minimum							1.75
Long-term debt maturities, 2018				0			$ 0
Long-term debt maturities, 2019				0			0
Long-term debt maturities, 2020				0			0
Long-term debt maturities, 2021				151,145,000			151,145,000
Long-term debt maturities, 2022				0			0
Long-term debt maturities, 2022 and thereafter				$ 1,125,000,000			$ 1,125,000,000
Amended Credit Agreement Due 2021 [Member]
Debt Instrument [Line Items]
Consolidated interest coverage ratio, minimum				2.5
Total consolidated leverage ratio, maximum				5.95	5.95	5.95
Senior secured unconsolidated leverage ratio maximum				3.0
Weighted average interest rate (in hundredths)				4.80%			4.80%
Amended Credit Agreement Due 2021 [Member] | Federal Funds Rate [Member]
Debt Instrument [Line Items]
Description of applicable interest rate on borrowings							Federal Funds Rate
Margin over basis rate (in hundredths)							0.50%
Amended Credit Agreement Due 2021 [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Description of applicable interest rate on borrowings							LIBOR
Margin over basis rate (in hundredths)							1.00%
Amended Credit Agreement Due 2021 [Member] | Scenario, Forecast [Member]
Debt Instrument [Line Items]
Total consolidated leverage ratio, maximum		5.5	5.75
Amended Credit Agreement Due 2017 [Member]
Debt Instrument [Line Items]
Effective date							Jun. 25, 2013
Termination date							Jan. 05, 2017
Fixed interest rate (in hundredths)				1.63%			1.63%
Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Maturity date							Mar. 03, 2021
Long-term borrowings				$ 151,145,000			$ 151,145,000	$ 162,645,000
Standby letters of credit issued under the Revolving Credit Facility				$ 45,226,000			$ 45,226,000
Revolving Credit Facility [Member] | Amended Credit Agreement Due 2021 [Member]
Debt Instrument [Line Items]
Credit Facility, maximum amount	$ 500,000,000
Revolving credit facility, term	5 years
5.5% Senior Notes due June 1, 2024 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)				5.50%			5.50%	5.50%
Maturity date							Jun. 01, 2024
Date public offering completed							May 27, 2014
Aggregate principal amount				$ 525,000,000			$ 525,000,000
Percentage of principal amount at which debt was issued (in hundredths)				100.00%			100.00%
Percentage of the principal amount repurchase offer under change of control provision (in hundredths)				101.00%			101.00%
Repurchase of debt due to decline in rating after consummation of change of control, period							90 days
7.5% Senior Notes due October 1, 2018 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)				7.50%			7.50%
5.75% Senior Notes due March 1, 2025 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)				5.75%			5.75%	5.75%
Maturity date							Mar. 01, 2025
Date public offering completed							Feb. 25, 2015
Aggregate principal amount				$ 250,000,000			$ 250,000,000
Percentage of principal amount at which debt was issued (in hundredths)				100.00%			100.00%
Percentage of the principal amount repurchase offer under change of control provision (in hundredths)				101.00%			101.00%
Repurchase of debt due to decline in rating after consummation of change of control, period							90 days
7.375% Senior Notes due 2020 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)				7.375%			7.375%
5.875% Senior Notes due March 1, 2027 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)				5.875%			5.875%	5.875%
Maturity date							Mar. 01, 2027
Date public offering completed							Feb. 14, 2017
Aggregate principal amount				$ 350,000,000			$ 350,000,000
Percentage of principal amount at which debt was issued (in hundredths)				100.00%			100.00%
Percentage of the principal amount repurchase offer under change of control provision (in hundredths)				101.00%			101.00%
Repurchase of debt due to decline in rating after consummation of change of control, period							90 days
7.375% Senior Notes due August 1, 2021 [Member]
Debt Instrument [Line Items]
Stated interest rate (in hundredths)				7.375%			7.375%

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Distributions of Available Cash - Additional Information (Details)	9 Months Ended
	Jun. 30, 2018 $ / shares
Distributions Made To Members Or Limited Partners [Abstract]
Distributions to its partners	45 days
Declaration date of quarterly distribution	Jul. 26, 2018
Distributions paid (in dollars per unit)	$ 0.60
Common Unit distribution on an annualized basis (in dollars per unit)	$ 2.40
Distribution date of quarterly distribution	Aug. 14, 2018
Date of record of quarterly distribution	Aug. 07, 2018

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Unit-Based Compensation Arrangements - Additional Information (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
	Aug. 06, 2013	Jun. 30, 2018	Jun. 24, 2017	Jun. 30, 2018	Jun. 24, 2017	Sep. 30, 2017
Distribution Equivalent Rights Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Compensation expense		$ 201	$ 205	$ 609	$ 640
Distribution Equivalent Rights Plan, terms				On January 17, 2017, the Partnership adopted the Distribution Equivalent Rights Plan (the “DER Plan”), which gives the Compensation Committee of the Partnership’s Board of Supervisors discretion to award distribution equivalent rights (“DERs”) to executive officers of the Partnership. Once awarded, DERs entitle the grantee to a cash payment each time the Board of Supervisors declares a cash distribution on the Partnership’s Common Units, which cash payment will be equal to an amount calculated by multiplying the number of unvested restricted units which are held by the grantee on the record date of the distribution, by the amount of the declared distribution per Common Unit.
2009 Restricted Unit Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Total number of Common Units authorized for issuance (in units)		2,400,000		2,400,000
Restricted Unit Plans, terms of award				In accordance with an August 6, 2013 amendment to the 2009 Restricted Unit Plan, unless otherwise stipulated by the Compensation Committee of the Partnership’s Board of Supervisors on or before the grant date, all restricted unit awards granted after the date of the amendment will vest 33.33% on each of the first three anniversaries of the award grant date. Prior to the August 6, 2013 amendment, unless otherwise stipulated by the Compensation Committee of the Partnership’s Board of Supervisors on or before the grant date, restricted units issued under the 2009 Restricted Unit Plan vest over time with 25% of the Common Units vesting at the end of each of the third and fourth anniversaries of the grant date and the remaining 50% of the Common Units vesting at the end of the fifth anniversary of the grant date. The 2009 Restricted Unit Plan participants are not eligible to receive quarterly distributions on, or vote, their respective restricted units until vested. Restricted units cannot be sold or transferred prior to vesting. The value of the restricted unit is established by the market price of the Common Unit on the date of grant, net of estimated future distributions during the vesting period. Restricted units are subject to forfeiture in certain circumstances as defined in the 2009 Restricted Unit Plan.
Awards Granted				424,431
Aggregate grant date fair value of restricted units awarded				$ 8,285
Unrecognized compensation cost		$ 4,322		$ 4,322
Weighted-average recognition period of compensation cost				1 year
Compensation expense		$ 1,715	1,372	$ 6,862	6,209
2018 Restricted Unit Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards Granted				0
2018 Restricted Unit Plan [Member] | Maximum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Total number of Common Units authorized for issuance (in units)		1,800,000		1,800,000
Long-Term Incentive Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Long-Term Incentive Plan, terms of award				The LTIP is a non-qualified, unfunded, long-term incentive plan for officers and key employees that provides for payment, in the form of cash, of an award of equity-based compensation at the end of a three-year performance period.
Measurement period of average distribution coverage ratio	3 years
Compensation expense		$ 595	$ (550)	$ 2,719	$ (2,026)
Liability included within accrued employment and benefit costs (or other liabilities, as applicable) related to estimated future payments under the LTIP		$ 4,356		$ 4,356		$ 1,637

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Unit-Based Compensation Arrangements - Summary of Activity for the Restricted Units Plans (Details) - 2009 Restricted Unit Plan [Member]	9 Months Ended
	Jun. 30, 2018 $ / shares shares
Restricted Units [Rollforward]
Outstanding, beginning of period (in units) | shares	621,045
Awarded (in units) | shares	424,431
Forfeited (in units) | shares	(13,992)
Vested (with Common Units issued) (in units) | shares	(335,253)
Outstanding, end of period (in units) | shares	696,231
Weighted Average Grant Date Fair Value Per Unit [Abstract]
Outstanding, beginning of period (in dollars per unit) | $ / shares	$ 22.10
Awarded (in dollars per unit) | $ / shares	19.52
Forfeited (in dollars per unit) | $ / shares	(19.70)
Vested (with Common Units issued) (in dollars per unit) | $ / shares	(24.39)
Outstanding, end of period (in dollars per unit) | $ / shares	$ 19.47

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Commitments and Contingencies - Additional Information (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Sep. 30, 2017
Commitments And Contingencies Disclosure [Abstract]
Accrued insurance liabilities	$ 71,303	$ 68,581
Portion of the estimated liability that exceeds insurance deductibles	$ 19,916	$ 18,626

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Guarantees - Additional Information (Details)	9 Months Ended
	Jun. 30, 2018 USD ($)
Guarantees [Abstract]
Transportation equipment remaining lease periods	2028
Maximum potential amount of aggregate future payments Partnership could be required to make	$ 16,407,000

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Pension Plans and Other Postretirement Benefits - Components of Net Periodic Benefit Costs (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Jun. 24, 2017	Jun. 30, 2018	Jun. 24, 2017
Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost	$ 69	$ 96	$ 208	$ 288
Amortization of prior service credits	(124)	0	(374)	0
Amortization of net loss (gain)	(163)	(98)	(491)	(292)
Net periodic benefit cost	(218)	(2)	(657)	(4)
United States [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost	944	1,041	2,832	3,123
Expected return on plan assets	(473)	(537)	(1,420)	(1,611)
Amortization of net loss (gain)	920	1,301	2,762	3,901
Net periodic benefit cost	$ 1,391	$ 1,805	$ 4,174	$ 5,413

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Pension Plans and Other Postretirement Benefits - Additional Information (Details) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2018	Jun. 24, 2017	Sep. 30, 2017
Components of net periodic benefit costs included in operating expenses [Abstract]
Contribution to defined pension benefit plan	$ 3,839	$ 7,542
Estimated obligation due to full withdrawal multi employer pension plans	22,773		$ 23,665
Defined Benefit Pension Plan [Member]
Components of net periodic benefit costs included in operating expenses [Abstract]
Defined benefit plan expected contribution to be paid for fiscal year	4,764
Contribution to defined pension benefit plan	3,839
Post-Retirement Benefits [Member]
Components of net periodic benefit costs included in operating expenses [Abstract]
Defined benefit plan expected contribution to be paid for fiscal year	1,243
Employer contribution for postretirement health care and life insurance	$ 847

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Amounts Reclassified Out of Accumulated Other Comprehensive Income - Reclassification out of accumulated other comprehensive (loss) income (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Jun. 30, 2018	Jun. 24, 2017	Jun. 30, 2018	Jun. 24, 2017
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance beginning		$ (27,298)	$ (43,221)	$ (28,812)	$ (45,832)
Other comprehensive income before reclassifications		0	0	0	(10)
Reclassifications to earnings		757	1,203	2,271	3,824
Other comprehensive income		757	1,203	2,271	3,814
Balance ending		(26,541)	(42,018)	(26,541)	(42,018)
Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance beginning		0	0	0	(205)
Other comprehensive income before reclassifications		0	0	0	(10)
Reclassifications to earnings	[1]	0	0	0	215
Other comprehensive income		0	0	0	205
Balance ending		0	0	0	0
Pension Benefits [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance beginning		(35,469)	(48,791)	(37,311)	(51,391)
Other comprehensive income		920	1,301	2,762	3,901
Balance ending		(34,549)	(47,490)	(34,549)	(47,490)
Amortization of Net Loss [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications to earnings	[2]	920	1,301	2,762	3,901
Post-Retirement Benefits [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance beginning		8,171	5,570	8,499	5,764
Other comprehensive income		(163)	(98)	(491)	(292)
Balance ending		8,008	5,472	8,008	5,472
Amortization of Net (Gain) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications to earnings	[2]	$ (163)	$ (98)	$ (491)	$ (292)

[1] Reclassification of realized losses on cash flow hedges are recognized in interest expense.

[2] These amounts are included in the computation of net periodic benefit cost. See Note 13, “Pension Plans and Other Postretirement Benefits.”

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Income Taxes - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Dec. 30, 2017	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Federal corporate income tax rate	35.00%	21.00%
Discrete deferred tax benefit	$ 1,086

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Segment Information - Additional Information (Details)	9 Months Ended
	Jun. 30, 2018 Segment
Segment Reporting [Abstract]
Number of operating segments	4
Number of reportable segments	3

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Segment Information - Disclosure by Reportable Segment and Reconciliation of Total Operating Segment Information (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Jun. 30, 2018	Jun. 24, 2017	Jun. 30, 2018	Jun. 24, 2017	Sep. 30, 2017
Revenues [Abstract]
Total revenues		$ 241,936	$ 222,895	$ 1,151,495	$ 990,780
Operating income (loss):
Total operating income (loss)		3,061	(11,062)	185,039	145,280
Reconciliation to net (loss) income:
Loss on debt extinguishment		0	0	0	1,567
Interest expense, net		19,512	18,502	58,428	54,820
Provision for (benefit from) income taxes		144	152	(749)	308
Net (loss) income		(16,595)	(29,716)	127,360	88,585
Depreciation and amortization [Abstract]
Total depreciation and amortization		31,259	31,825	94,593	95,756
Assets [Abstract]
Total assets		2,131,533		2,131,533		$ 2,171,283
Operating/Reportable Segments [Member] | Propane [Member]
Revenues [Abstract]
Total revenues		205,400	188,406	990,344	843,519
Operating income (loss):
Total operating income (loss)	[1]	28,073	11,323	245,845	201,332
Depreciation and amortization [Abstract]
Total depreciation and amortization		27,875	27,787	83,944	83,243
Assets [Abstract]
Total assets		2,020,928		2,020,928		2,066,997
Operating/Reportable Segments [Member] | Fuel Oil and Refined Fuels [Member]
Revenues [Abstract]
Total revenues		15,400	12,886	82,414	69,612
Operating income (loss):
Total operating income (loss)		(891)	199	10,132	9,875
Depreciation and amortization [Abstract]
Total depreciation and amortization		571	625	1,866	1,923
Assets [Abstract]
Total assets		49,525		49,525		49,863
Operating/Reportable Segments [Member] | Natural Gas and Electricity [Member]
Revenues [Abstract]
Total revenues		10,403	11,923	43,942	44,229
Operating income (loss):
Total operating income (loss)		2,192	2,806	11,131	11,461
Depreciation and amortization [Abstract]
Total depreciation and amortization		0	0	0	0
Assets [Abstract]
Total assets		12,679		12,679		12,455
Operating/Reportable Segments [Member] | All Other [Member]
Revenues [Abstract]
Total revenues		10,733	9,680	34,795	33,420
Operating income (loss):
Total operating income (loss)		(4,607)	(5,747)	(14,821)	(16,139)
Depreciation and amortization [Abstract]
Total depreciation and amortization		57	76	163	222
Assets [Abstract]
Total assets		3,576		3,576		2,147
Operating/Reportable Segments [Member] | Corporate [Member]
Operating income (loss):
Total operating income (loss)		(21,706)	(19,643)	(67,248)	(61,249)
Depreciation and amortization [Abstract]
Total depreciation and amortization		2,756	$ 3,337	8,620	$ 10,368
Assets [Abstract]
Total assets		$ 44,825		$ 44,825		$ 39,821

[1] Includes the loss on sale of business of $4,823 for the nine months ended June 30, 2018 (see Note 3).

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Segment Information - Disclosure by Reportable Segment and Reconciliation of Total Operating Segment Information (Parenthetical) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Dec. 30, 2017	Jun. 30, 2018	Jun. 24, 2017
Segment Reporting Information [Line Items]
Loss on sale of business	$ 4,823	$ 4,823	$ 0
Operating/Reportable Segments [Member] | Propane [Member]
Segment Reporting Information [Line Items]
Loss on sale of business		$ 4,823