10-Q/A

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q/A

(Amendment No. 1)

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

For the quarterly period ended June 23, 2012

¨ 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 incorporation or organization)	(I.R.S. Employer 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  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§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  x    No  ¨

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

Large accelerated filer	x	Accelerated filer	¨
Non-accelerated filer	¨  (do not check if a smaller reporting company)	Smaller reporting company	¨

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

EXPLANATORY NOTE

This Amendment No. 1 to the Quarterly Report on Form 10–Q for Suburban Propane Partners, L.P. for the quarterly period ended June 23, 2012, as filed with the Securities and Exchange Commission on August 2, 2012 (the “Original Filing”), is being filed to (i) amend “Note 16. Subsequent Event—Acquisition of Inergy Propane” in Part I, Item 1 to properly reflect the acquisition costs incurred in connection with the Inergy Propane Acquisition in the pro forma results of operations for the nine month period ended June 25, 2011, and (ii) to include certain eXtensible Business Reporting Language (“XBRL”) information in Exhibit 101 that contained certain incorrect Level 4 data within the Subsequent Event footnote from the timely filed Original Filing, in accordance with Rule 405 of Regulation S–T.

Exhibit 101 provides the following materials from the Original Filing, formatted in XBRL: (i) Condensed Consolidated Balance Sheets; (ii) Condensed Consolidated Statements of Comprehensive Income; (iii) Condensed Consolidated Statement of Cash Flows; and (iv) Notes to Condensed Consolidated Financial Statements.

This Amendment No. 1 speaks as of the date of the Original Filing, and does not reflect subsequent events occurring after the date of the Original Filing. Other than as described above, no other changes have been made to the Original Filing.

SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)

(unaudited)

	June 23,			September 24,
	2012			2011
ASSETS
Current assets:
Cash and cash equivalents	$	115,804		$	149,553
Accounts receivable, less allowance for doubtful accounts of $5,990 and $6,960, respectively		62,478			66,630
Inventories		52,331			65,907
Other current assets		18,555			15,732
Total current assets		249,168			297,822
Property, plant and equipment, net		327,212			338,125
Goodwill		277,651			277,651
Other assets		42,033			42,861
Total assets	$	896,064		$	956,459
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable	$	26,309		$	37,456
Accrued employment and benefit costs		12,371			22,951
Customer deposits and advances		36,634			57,476
Other current liabilities		35,770			33,631
Total current liabilities		111,084			151,514
Long-term borrowings		348,331			348,169
Accrued insurance		43,604			42,891
Other liabilities		55,515			55,667
Total liabilities		558,534			598,241
Commitments and contingencies
Partners’ capital:
Common Unitholders (35,545 and 35,429 units issued and outstanding at June 23, 2012 and September 24, 2011, respectively)		394,086			418,134
Accumulated other comprehensive loss		(56,556	)		(59,916	)
Total partners’ capital		337,530			358,218
Total liabilities and partners’ capital	$	896,064		$	956,459

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 23,			June 25,
	2012			2011
Revenues
Propane	$	142,681		$	169,258
Fuel oil and refined fuels		17,533			22,528
Natural gas and electricity		12,119			16,691
All other		7,268			8,086
		179,601			216,563
Costs and expenses
Cost of products sold		88,776			125,175
Operating		65,369			68,747
General and administrative		13,778			12,618
Acquisition-related costs		5,950			—
Depreciation and amortization		8,472			9,670
		182,345			216,210
Operating (loss) income		(2,744	)		353
Interest expense, net		6,479			6,867
Loss before provision for income taxes		(9,223	)		(6,514	)
Provision for income taxes		100			273
Net loss	$	(9,323	)	$	(6,787	)
Loss per Common Unit—basic	$	(0.26	)	$	(0.19	)
Weighted average number of Common Units outstanding—basic		35,653			35,540
Loss per Common Unit—diluted	$	(0.26	)	$	(0.19	)
Weighted average number of Common Units outstanding—diluted		35,653			35,540

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 23,			June 25,
	2012			2011
Revenues
Propane	$	666,796		$	786,968
Fuel oil and refined fuels		92,262			124,448
Natural gas and electricity		51,878			68,348
All other		26,177			29,208
		837,113			1,008,972
Costs and expenses
Cost of products sold		480,751			571,511
Operating		202,604			213,831
General and administrative		40,231			37,399
Severance charges		—			2,000
Acquisition-related costs		5,950			—
Depreciation and amortization		23,906			26,304
		753,442			851,045
Operating income		83,671			157,927
Loss on debt extinguishment		507			—
Interest expense, net		19,742			20,532
Income before (benefit from) provision for income taxes		63,422			137,395
(Benefit from) provision for income taxes		(60	)		737
Net income	$	63,482		$	136,658
Income per Common Unit—basic	$	1.78		$	3.85
Weighted average number of Common Units outstanding—basic		35,616			35,517
Income per Common Unit—diluted	$	1.77		$	3.83
Weighted average number of Common Units outstanding—diluted		35,794			35,712

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 23, 2012			June 25, 2011
Cash flows from operating activities:
Net income	$	63,482		$	136,658
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization		23,906			26,304
Loss on debt extinguishment		507			—
Other, net		6,424			1,916
Changes in assets and liabilities:
Accounts receivable		4,152			(22,685	)
Inventories		13,576			7,331
Other current and noncurrent assets		(1,644	)		3,679
Accounts payable		(11,147	)		(7,466	)
Accrued employment and benefit costs		(10,580	)		(7,296	)
Customer deposits and advances		(20,842	)		(31,411	)
Accrued insurance		(1,177	)		(3,339	)
Other current and noncurrent liabilities		6,593			6,150
Net cash provided by operating activities		73,250			109,841
Cash flows from investing activities:
Capital expenditures		(14,384	)		(17,241	)
Acquisition of business		—			(3,195	)
Proceeds from sale of property, plant and equipment		2,367			5,567
Net cash (used in) investing activities		(12,017	)		(14,869	)
Cash flows from financing activities:
Repayments of long-term borrowings		(100,000	)		—
Proceeds from long-term borrowings		100,000			—
Issuance costs associated with borrowings		(4,192	)		—
Partnership distributions		(90,790	)		(90,433	)
Net cash (used in) financing activities		(94,982	)		(90,433	)
Net (decrease) increase in cash and cash equivalents		(33,749	)		4,539
Cash and cash equivalents at beginning of period		149,553			156,908
Cash and cash equivalents at end of period	$	115,804		$	161,447

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 STATEMENT OF PARTNERS’ CAPITAL

(in thousands)

(unaudited)

	Number of Common Units		Common Unitholders			Accumulated Other Comprehensive (Loss)			Total Partners’ Capital			Comprehensive Income
Balance at September 24, 2011		35,429	$	418,134		$	(59,916	)	$	358,218
Net income				63,482						63,482		$	63,482
Other comprehensive income:
Unrealized losses on cash flow hedges							(2,234	)		(2,234	)		(2,234	)
Reclassification of realized losses on cash flow hedges into earnings							2,008			2,008			2,008
Amortization of net actuarial losses and prior service credits into earnings							3,586			3,586			3,586
Comprehensive income												$	66,842
Partnership distributions				(90,790	)					(90,790	)
Common Units issued under Restricted Unit Plans		116
Compensation cost recognized under Restricted Unit Plans, net of forfeitures				3,260						3,260
Balance at June 23, 2012		35,545	$	394,086		$	(56,556	)	$	337,530

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

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SUBURBAN PROPANE PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(dollars in thousands, except 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 35,544,766 Common Units outstanding at June 23, 2012. 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 corporate entities (collectively referred to as the “Corporate Entities”) and, as such, are subject to corporate level federal and state income tax.

Suburban Energy Finance Corporation, 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 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 24, 2011. 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.

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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 13 weeks in duration. When the Partnership’s fiscal year is 53 weeks long, the corresponding fourth quarter is 14 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 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 billing 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.

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 depreciation and amortization of long-lived assets, insurance and litigation reserves, severance benefits, pension and other postretirement benefit liabilities and costs, purchase accounting, valuation of derivative instruments, asset valuation assessments, tax valuation allowances, as well as the allowance for doubtful accounts. Actual results could differ from those estimates, making it reasonably possible that a change in these estimates could occur in the near term.

3. 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 maturity of these instruments.

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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 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 options contracts and, in certain instances, over-the-counter options contracts (collectively, “derivative instruments”) to hedge price risk associated with propane and fuel oil physical inventories, as well as anticipated future purchases of propane or fuel oil to be used in its operations and to ensure adequate supply during periods of high demand. 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. 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 futures, options and forward contracts 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, 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  ¹/₂ 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. 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 (Level 1 inputs), 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 gross fair value of the Partnership’s derivative instruments and their location in the condensed consolidated balance sheet as of June 23, 2012 and September 24, 2011, respectively:

	As of June 23, 2012			As of September 24, 2011
Asset Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity options	Other current assets	$	7,263	Other current assets	$	3,710
	Other assets		—	Other assets		612
Commodity futures	Other current assets		1,952	Other current assets		1,132
		$	9,215		$	5,454
Liability Derivatives	Location	Fair Value		Location	Fair Value
Derivatives designated as hedging instruments:
Interest rate swaps	Other current liabilities	$	2,646	Other current liabilities	$	2,662
	Other liabilities		2,176	Other liabilities		1,934
		$	4,822		$	4,596
Derivatives not designated as hedging instruments:
Commodity options	Other current liabilities	$	1,338	Other current liabilities	$	2,407
	Other liabilities		—	Other liabilities		69
		$	1,338		$	2,476

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 June 23, 2012						Nine Months Ended June 25, 2011
	Assets			Liabilities			Assets			Liabilities
Opening balance of over-the-counter options	$	1,780		$	118		$	1,509		$	29
Beginning balance realized during the period		(758	)		(15	)		(1,509	)		(29	)
Contracts purchased during the period		3,245			259			2,778			226
Change in the fair value of beginning balance		2,678			669			—			—
Closing balance of over-the-counter options	$	6,945		$	1,031		$	2,778		$	226

As of June 23, 2012 and September 24, 2011, the Partnership’s outstanding commodity-related derivatives had a weighted average maturity of approximately 3 months and 4 months, respectively.

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The effect of the Partnership’s derivative instruments on the condensed consolidated statements of operations for the three and nine months ended June 23, 2012 and June 25, 2011 are as follows:

	Three months ended June 23, 2012								Three months ended June 25, 2011
Derivatives in Cash Flow Hedging	Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)					Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)
Relationships	(Effective Portion)			Location		Amount			(Effective Portion)			Location		Amount
Interest rate swap	$	(1,856	)		Interest expense	$	(670	)	$	(1,077	)		Interest expense	$	(719	)
	$	(1,856	)			$	(670	)	$	(1,077	)			$	(719	)

Derivatives Not Designated as Hedging Instruments	Location of Gains (Losses)  Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income		Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income
Commodity options	Cost of products sold	$	6,465	Cost of products sold	$	(516	)
Commodity futures	Cost of products sold		1,753	Cost of products sold		203
		$	8,218		$	(313	)

	Nine months ended June 23, 2012							Nine months ended June 25, 2011
Derivatives in Cash Flow Hedging	Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)				Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)
Relationships	(Effective Portion)			Location	Amount			(Effective Portion)			Location	Amount
Interest rate swap	$	(2,234	)	Interest expense	$	(2,008	)	$	(851	)	Interest expense	$	(2,147	)
	$	(2,234	)		$	(2,008	)	$	(851	)		$	(2,147	)

Derivatives Not Designated as Hedging Instruments	Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income		Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income
Commodity options	Cost of products sold	$	6,350	Cost of products sold	$	283
Commodity futures	Cost of products sold		820	Cost of products sold		1,954
		$	7,170		$	2,237

Bank Debt and Senior Notes. The fair value of the Revolving Credit Facility (defined below) approximates the carrying value since the interest rates are periodically adjusted to reflect market conditions. Based upon quoted market prices, qualifying as a Level 1 fair value input, the fair value of the Partnership’s 2020 senior notes was $262,500 and $248,500 as of June 23, 2012 and September 24, 2011, respectively.

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4. 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 23,		September 24,
	2012		2011
Propane, fuel oil and refined fuels and natural gas	$	50,969	$	64,601
Appliances and related parts		1,362		1,306
	$	52,331	$	65,907

5. Goodwill

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 in August of each year, or when an event occurs or circumstances change that would indicate potential impairment. 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:

	As of
	June 23,		September 24,
	2012		2011
Propane	$	265,313	$	265,313
Fuel oil and refined fuels		4,438		4,438
Natural gas and electricity		7,900		7,900
	$	277,651	$	277,651

6. 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 restricted units granted under the restricted unit plans 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 unvested 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 177,431 and 194,668 units for the nine months ended June 23, 2012 and June 25, 2011, respectively, to reflect the potential dilutive effect of the unvested restricted units outstanding using the treasury stock method.

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7. Long-Term Borrowings

Long-term borrowings consist of the following:

	As of
	June 23,		September 24,
	2012		2011
7.375% senior notes, due March 15, 2020, net of unamortized discount of $1,669 and $1,831, respectively	$	248,331	$	248,169
Revolving credit facility, due January 5, 2017		100,000		100,000
	$	348,331	$	348,169

On March 23, 2010, the Partnership and its wholly-owned subsidiary, Suburban Energy Finance Corporation, issued $250,000 in aggregate principal amount of 7.375% senior notes due 2020 (the “2020 Senior Notes”). The 2020 Senior Notes were issued at 99.136% of the principal amount. The Partnership’s obligations under the 2020 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 2020 Senior Notes are structurally subordinated to, which means they rank effectively behind, any debt and other liabilities of the Operating Partnership. The 2020 Senior Notes mature on March 15, 2020 and require semi-annual interest payments in March and September. The Partnership is permitted to redeem some or all of the 2020 Senior Notes any time at redemption prices specified in the indenture governing the 2020 Senior Notes. In addition, the 2020 Senior Notes 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.

The Operating Partnership has a credit agreement, as amended on January 5, 2012 (the “Amended Credit Agreement”) that provides for a five-year $250,000 revolving credit facility (the “Revolving Credit Facility”) of which, $100,000 was outstanding as of June 23, 2012 and September 24, 2011. The Amended Credit Agreement amends the previous credit agreement to, among other things, extend the maturity date from June 25, 2013 to January 5, 2017, reduce the borrowing rate and commitment fees, and amend certain affirmative and negative covenants. 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.

At the time the amendment was entered into, the Operating Partnership had existing borrowings of $100,000 under the revolving credit facility of the previous credit agreement, which borrowings have been rolled into the Revolving Credit Facility of the Amended Credit Agreement. In addition, at the time the amendment was entered into, the Operating Partnership had letters of credit issued under the revolving credit facility of the previous credit agreement primarily in support of retention levels under its self-insurance programs, all of which have been rolled into the Revolving Credit Facility of the Amended Credit Agreement. As of June 23, 2012, the Partnership had standby letters of credit issued under the Revolving Credit Facility in the aggregate amount of $46,926 which expire periodically through April 15, 2013. Therefore, as of June 23, 2012 the Partnership had available borrowing capacity of $103,074 under the Revolving Credit Facility.

In connection with the previous revolving credit facility, the Operating Partnership entered into an interest rate swap agreement with a notional amount of $100,000 and an effective date of March 31, 2010 and termination date of June 25, 2013. Under the interest rate swap agreement, the Operating Partnership will pay a fixed interest rate of 3.12% to the issuing lender on the notional principal amount outstanding, effectively fixing the LIBOR portion of the interest rate at 3.12%. In return, the issuing lender will pay to the Operating Partnership a floating rate, namely LIBOR, on the same notional principal amount. The interest rate swap has been designated as a cash flow hedge.

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In connection with the Amended Credit Agreement, the Operating Partnership entered into a forward starting interest rate swap agreement with a June 25, 2013 effective date, which is commensurate with the maturity of the existing interest rate swap agreement, and a termination date of January 5, 2017. Under this forward starting interest rate swap agreement, the Operating Partnership will pay a fixed interest rate of 1.63% to the issuing lender on the notional principal amount outstanding, effectively fixing the LIBOR portion of the interest rate at 1.63%. In return, the issuing lender will pay to the Operating Partnership a floating rate, namely LIBOR, on the same notional principal amount. The forward starting interest rate swap has been designated as a cash flow hedge.

Borrowings under the Revolving Credit Facility bear interest at prevailing interest rates based upon, at the Operating Partnership’s option, LIBOR plus the applicable margin or the base rate, defined as the higher of the Federal Funds Rate plus  ¹/₂ of 1%, the agent bank’s prime rate, or LIBOR plus 1%, plus in each case the applicable margin. The applicable margin is dependent upon the Partnership’s ratio of total debt to EBITDA on a consolidated basis, as defined in the Revolving Credit Facility. As of June 23, 2012, the interest rate for the Revolving Credit Facility was approximately 2.7%. The interest rate and the applicable margin will be reset at the end of each calendar quarter.

The Partnership acts as a guarantor 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.

The Amended Credit Agreement and the 2020 Senior Notes both contain various restrictive and affirmative covenants applicable to the Operating Partnership 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. The Amended Credit Agreement contains certain financial covenants (a) requiring the Partnership’s consolidated interest coverage ratio, as defined, 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, of the Partnership from being greater than 4.75 to 1.0 as of the end of any fiscal quarter; and (c) prohibiting the Operating Partnership’s senior secured consolidated leverage ratio, as defined, from being greater than 3.0 to 1.0 as of the end of any fiscal quarter. Under the indenture governing the 2020 Senior Notes, the Partnership is 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 the Partnership’s consolidated fixed charge coverage ratio, as defined, is greater than 1.75 to 1.0. The Partnership and the Operating Partnership were in compliance with all covenants and terms of the 2020 Senior Notes and the Amended Credit Agreement as of June 23, 2012.

On April 25, 2012, the Partnership received consents from the requisite lenders under the Amended Credit Agreement to enable the Partnership to incur additional indebtedness, make amendments to the Amended Credit Agreement to adjust certain covenants, and otherwise perform our obligations as contemplated by the Inergy Propane Acquisition see Note 16. Subsequent Event – Acquisition of Inergy Propane for a description of further amendments to the Amended Credit Agreement and the new senior notes issued by the Partnership in connection with the Inergy Propane Acquisition.

Debt origination costs representing the costs incurred in connection with the placement of, and the subsequent amendment to, long-term borrowings are capitalized within other assets and amortized on a straight-line basis over the term of the respective debt agreements. In connection with the execution of the Amendment Credit Agreement, the Partnership recognized a non-cash charge of $507 to write-off a portion of unamortized debt origination costs associated with the previous credit agreement, and capitalized $2,420 for origination costs incurred with the amendment. During the third quarter of fiscal 2012, the Partnership capitalized $1,772 for origination costs incurred in connection with the issuance of new senior notes in August 2012 in connection with the Inergy Propane Acquisition. Other assets at June 23, 2012 and September 24, 2011 include debt origination costs with a net carrying amount of $9,747 and $7,207, respectively.

The aggregate amounts of long-term debt maturities subsequent to June 23, 2012 are as follows: fiscal 2012 through fiscal 2016: $-0-; and thereafter: $350,000.

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8. Distributions of Available Cash

The Partnership makes distributions to its limited partners no later than 45 days after the end of each fiscal quarter of the Partnership 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 18, 2012, the Partnership announced a quarterly distribution of $0.8525 per Common Unit, or $3.41 per Common Unit on an annualized basis, in respect of the third quarter of fiscal 2012, payable on August 7, 2012 to holders of record on July 31, 2012.

9. 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. In fiscal 2000 and fiscal 2009, the Partnership adopted the Suburban Propane Partners, L.P. 2000 Restricted Unit Plan and 2009 Restricted Unit Plan (collectively, the “Restricted Unit Plans”), respectively, which authorize 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 Restricted Unit Plans was 1,902,122 as of June 23, 2012. Unless otherwise stipulated by the Compensation Committee of the Board of Supervisors on or before the grant date, restricted units issued under the Restricted Unit Plans vest over time with 25% of the Common Units vesting on each of the third and fourth anniversaries of the grant date and the remaining 50% of the Common Units vesting on the fifth anniversary of the grant date. The Restricted Unit Plans participants are not eligible to receive quarterly distributions with respect to or vote their respective restricted units until vested. Because each restricted unit represents a promise to issue a Common Unit at a future date, restricted units cannot be sold or transferred prior to vesting. The fair 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 and forfeitures during the vesting period. Restricted units are subject to forfeiture in certain circumstances as defined in the Restricted Unit Plans. Compensation expense for the unvested awards is recognized ratably over the vesting periods and is net of estimated forfeitures.

During the nine months ended June 23, 2012, the Partnership awarded 108,674 restricted units under the Restricted Unit Plans at an aggregate grant date fair value of $3,543. The following is a summary of activity for the Restricted Unit Plans for the nine months ended June 23, 2012:

				Weighted
				Average Grant
				Date Fair Value
	Units			Per Unit
Outstanding September 24, 2011		485,423		$	32.71
Awarded		108,674			32.60
Forfeited		(11,093	)		(30.63	)
Issued		(115,911	)		(31.77	)
Outstanding June 23, 2012		467,093		$	33.04

As of June 23, 2012, unrecognized compensation cost related to unvested restricted units awarded under the Restricted Unit Plans amounted to $6,264. Compensation cost associated with unvested awards is expected to be recognized over a weighted-average period of 1.8 years. Compensation expense recognized under the Restricted Unit Plans, net of forfeitures, for the three and nine months ended June 23, 2012 was $911 and $3,261, respectively, and $737 and $3,136 for the three and nine months ended June 25, 2011, respectively.

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Long-Term Incentive Plan. The Partnership has a non-qualified, unfunded long-term incentive plan for officers and key employees (the “LTIP”) which 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 market performance of the Partnership’s Common Units on the basis of total return to Unitholders (“TRU”) compared to the TRU of a predetermined peer group consisting solely of other master limited partnerships, approved by the Compensation Committee of the Board of Supervisors, over the same three-year performance period. 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 23, 2012 was $(49) and $643, respectively, and $31 and $1,532 for the three and nine months ended June 25, 2011, respectively. As of June 23, 2012 and September 24, 2011, the Partnership had a liability included within accrued employment and benefit costs (or other liabilities, as applicable) of $2,471 and $5,164, respectively, related to estimated future payments under the LTIP.

10. 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 23, 2012 and September 24, 2011, the Partnership had accrued insurance liabilities of $51,664 and $52,841, respectively, representing the total estimated losses under these self-insurance programs. For the portion of the estimated self-insurance liability that exceeds insurance deductibles, the Partnership records an asset within other assets (or other current assets, as applicable) related to the amount of the liability expected to be covered by insurance which amounted to $16,943 and $17,513 as of June 23, 2012 and September 24, 2011, respectively.

Legal Matters. The Partnership’s operations are subject to all 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 arising in the ordinary course of business, both as a result of these operating hazards and risks, and as a result of other aspects of its business. In this last regard, the Partnership currently is a defendant in suits in several states, including two putative class actions in which no class has yet been certified. The complaints allege a number of commercial claims, including as to the Partnership’s pricing, fee disclosure and tank ownership, under various consumer statutes, the Uniform Commercial Code, common law and antitrust law. Based on the nature of the allegations under these commercial suits, the Partnership believes that the suits are without merit and the Partnership is contesting each of these suits vigorously. With respect to the pending commercial suits, other than for legal defense fees and expenses, based on the merits of the allegations and discovery to date, no liability for a loss contingency is required.

11. 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 2019. 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 $10,119 as of June 23, 2012. The fair value of residual value guarantees for outstanding operating leases was de minimis as of June 23, 2012 and September 24, 2011.

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12. 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 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Interest cost	$	1,577		$	1,706		$	4,733		$	5,117
Expected return on plan assets		(1,416	)		(1,574	)		(4,249	)		(4,721	)
Recognized net actuarial loss		1,318			1,180			3,953			3,540
Net periodic benefit cost	$	1,479		$	1,312		$	4,437		$	3,936

	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	June 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Service cost	$	2		$	2		$	5		$	6
Interest cost		200			214			602			641
Amortization of prior service costs		(122	)		(122	)		(367	)		(367	)
Recognized net actuarial loss		—			(9	)		—			(27	)
Net periodic benefit cost	$	80		$	85		$	240		$	253

There are no projected minimum employer cash contribution requirements under ERISA laws for fiscal 2012 under our defined benefit pension plan. The projected annual contribution requirements related to the Partnership’s postretirement health care and life insurance benefit plan for fiscal 2012 is $1,669, of which $1,062 has been contributed during the nine months ended June 23, 2012.

13. 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, as a separate legal entity, and the Operating Partnership are not subject to income tax at the Partnership level. Rather, the taxable income or loss attributable to the Partnership, as a separate legal entity, and to the Operating Partnership, which may vary substantially from the income 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 individual partners. 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 information regarding each partner’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 alternative minimum tax. A full valuation allowance has been provided against the deferred tax assets 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.

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14. Segment Information

The Partnership manages and evaluates its operations in five 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 the summary of significant accounting policies Note in the Partnership’s Annual Report on Form 10-K for the fiscal year ended September 24, 2011.

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, and activities from the Partnership’s HomeTown Hearth & Grill and Suburban Franchising subsidiaries.

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The following table presents certain relevant financial information 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 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Revenues:
Propane	$	142,681		$	169,258		$	666,796		$	786,968
Fuel oil and refined fuels		17,533			22,528			92,262			124,448
Natural gas and electricity		12,119			16,691			51,878			68,348
All other		7,268			8,086			26,177			29,208
Total revenues	$	179,601		$	216,563		$	837,113		$	1,008,972
Operating income:
Propane	$	25,270		$	20,434		$	139,251		$	193,700
Fuel oil and refined fuels		(1,789	)		(318	)		4,142			14,437
Natural gas and electricity		1,416			1,789			5,759			10,409
All other		(4,029	)		(3,433	)		(10,358	)		(8,947	)
Corporate		(23,612	)		(18,119	)		(55,123	)		(51,672	)
Total operating income		(2,744	)		353			83,671			157,927
Reconciliation to net income:
Loss on debt extinguishment		—			—			507			—
Interest expense, net		6,479			6,867			19,742			20,532
Provision for income taxes		100			273			(60	)		737
Net income	$	(9,323	)	$	(6,787	)	$	63,482		$	136,658
Depreciation and amortization:
Propane	$	5,142		$	5,011		$	14,997		$	15,326
Fuel oil and refined fuels		1,433			1,378			2,595			2,691
Natural gas and electricity		79			225			382			672
All other		19			34			72			192
Corporate		1,799			3,022			5,860			7,423
Total depreciation and amortization	$	8,472		$	9,670		$	23,906		$	26,304

	As of
	June 23, 2012		September 24, 2011
Assets:
Propane	$	685,576	$	706,008
Fuel oil and refined fuels		38,765		44,973
Natural gas and electricity		14,599		18,675
All other		3,693		3,719
Corporate		153,431		183,084
Total assets	$	896,064	$	956,459

15. Recently Issued Accounting Pronouncements

In June 2011, the FASB issued an accounting standards update to provide guidance on increasing the prominence of items reported in other comprehensive income. This update eliminates the option to present components of other comprehensive income as part of the statement of partners’ capital and requires net income and the components of other comprehensive income be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. Early adoption of this updated guidance is permitted, and it becomes effective retrospectively for fiscal years beginning after December 15, 2011, which will be the first quarter of the Partnership’s 2013 fiscal year. This update does not change the items that must be reported in other comprehensive income but will require the Partnership to change its historical practice of showing comprehensive income within the Statement of Partners’ Capital.

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In September 2011, the FASB issued an accounting standards update allowing companies to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, as a result of the qualitative assessment, it is more likely than not that the fair value of a reporting unit is less than its carrying amount, a more detailed two-step goodwill impairment test would be performed to identify a potential goodwill impairment and measure the amount of loss to be recognized, if any. The standard is effective for annual and interim goodwill impairment tests performed for fiscal years beginning after December 15, 2011, which will be the Partnership’s 2013 fiscal year. Early adoption is permitted. The adoption of this standard is not expected to impact the Partnership’s financial position, results of operations or cash flows.

16. Subsequent Event – Acquisition of Inergy Propane

On August 1, 2012 (the “Acquisition Date”), the Partnership completed the acquisition of the sole membership interest in Inergy Propane, LLC, including certain wholly-owned subsidiaries of Inergy Propane LLC, and the assets of Inergy Sales and Service, Inc. (“Inergy Sales”). The acquired interests and assets are collectively referred to as “Inergy Propane.” As of the Acquisition Date, Inergy Propane consisted of the former retail propane assets and operations of Inergy, L.P. (“Inergy”).

The acquisition of Inergy Propane (the “Inergy Propane Acquisition”) was consummated pursuant to a definitive agreement dated April 25, 2012 with Inergy, Inergy GP, LLC and Inergy Sales, as amended (the “Contribution Agreement”). Prior to the Acquisition Date, Inergy Propane transferred its interest in certain subsidiaries, as well as all of its rights and interests in the assets and properties of its wholesale propane supply, marketing and distribution business, and its rights and interest in the assets and properties of its West Coast natural gas liquids business, to Inergy. These assets were not included as part of the Inergy Propane business at the time of the transfer of the membership interests in Inergy Propane to the Partnership and were not part of the Inergy Propane Acquisition. On the Acquisition Date, Inergy Propane and its remaining wholly-owned subsidiaries acquired became subsidiaries of the Partnership. The results of operations of Inergy Propane will be included in the Partnership’s results of operations beginning on the Acquisition Date.

Pursuant to the Contribution Agreement, the Partnership agreed to issue $600,000 in new common units in the aggregate to Inergy and Inergy Sales (the “Equity Consideration”). In accordance with the Contribution Agreement, the number of common units to be issued to Inergy and Inergy Sales in the aggregate is determined by dividing $600,000 by the average of the high and low sales prices of the Partnership’s common units for the twenty consecutive trading days ending on the day prior to the execution of the Contribution Agreement, which was determined to be $43.1885, resulting in 13,893 common units.

Also pursuant to the Contribution Agreement, the Partnership and its wholly-owned subsidiary Suburban Energy Finance Corp. commenced an offer to exchange (the “Exchange Offers”) any and all of the outstanding unsecured 7% Senior Notes due 2018 and 6 ⁷/₈% Senior Notes due 2021 issued by Inergy and Inergy Finance Corp., which had an aggregate principal amount outstanding of $1,200,000 (collectively, the “Inergy Notes”), for a combination of $1,000,000 in aggregate principal amount of new unsecured 7 ¹/₂% Senior Notes due 2018 and 7 ³/₈% Senior Notes due 2021 (collectively, the “SPH Notes”) issued by the Partnership and Suburban Energy Finance Corp. and up to $200,000 in cash to be paid to tendering noteholders (the “Exchange Offer Cash Consideration”). Pursuant to the Contribution Agreement, the Partnership was required to pay Inergy the difference, if any, between $200,000 and the actual Exchange Offer Cash Consideration paid in accordance with the terms of the Exchange Offers (such payment, the “Inergy Cash Consideration”). The Contribution Agreement provides that the Partnership will offer $65,000 in aggregate cash consent payments in connection with the Exchange Offers and that Inergy will pay $36,500 to the Partnership in cash on the Acquisition Date. The Exchange Offers expired and settled on August 1, 2012 (the “Settlement Date”). On the Settlement Date, the Partnership had received tenders and consents from holders representing approximately 98.09% of the total outstanding principal amount of the 2018 Inergy Notes, and tenders and consents from holders representing approximately 99.74% of the total outstanding principal amount of the 2021 Inergy Notes. Based on the results of the Exchange Offers, the Exchange Offer Cash Consideration due to tendering Inergy noteholders was $184,761. The Inergy Cash Consideration was satisfied by the issuance of 308 common units to Inergy and therefore, when combined with the Equity Consideration, the Partnership issued 14,201 common units in the aggregate to Inergy and Inergy Sales on August 1, 2012. Inergy will subsequently distribute 14,058 of such common units to its unitholders and will retain 1% of such common units, or 143 common units.

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On April 25, 2012, the Partnership received consents from the requisite lenders under the Amended Credit Agreement to enable it to incur additional indebtedness, make amendments to the Amended Credit Agreement to adjust certain covenants, and otherwise perform our obligations as contemplated by the Inergy Propane Acquisition. On August 1, 2012, the Operating Partnership executed an amendment to the Amended Credit Agreement to, among other things, provide for (i) a $250,000 senior secured 364-day incremental term loan facility (the “364-Day Facility”) and (ii) an increase in our revolving credit facility under the Amended Credit Agreement from $250,000 to $400,000. On the Acquisition Date, the Operating Partnership drew $225,000 on the 364-Day Facility, which, together with cash received from Inergy (pursuant to the Contribution Agreement) and cash on hand, was used to pay (i) the consent fees and the Exchange Offer Cash Consideration, (ii) costs and fees related to the Exchange Offers, and (iii) costs and expenses related to the Inergy Propane Acquisition. The Partnership intends to repay such borrowings with an equity financing in the future, subject to market conditions.

The amendment to the Amended Credit Agreement also amended certain restrictive and affirmative covenants applicable to the Operating Partnership and the Partnership, as well as certain financial covenants, including (a) requiring the Partnership’s consolidated interest coverage ratio, as defined in the amendment, to be not less than 2.0 to 1.0 as of the end of any fiscal quarter; (b) prohibiting the total consolidated leverage ratio, as defined in the amendment, of the Partnership from being greater than 7.0 to 1.0 as of the end of any fiscal quarter. The minimum consolidated interest coverage ratio increases over time, and commencing with the second quarter of fiscal 2015, such minimum ratio will be 2.5 to 1.0. The maximum consolidated leverage ratio decreases over time, and commencing with the first quarter of fiscal 2015, such maximum ratio will be 4.75 to 1.0.

The preliminary fair value of the purchase price for Inergy Propane was $1,896,860, consisting of: (i) $1,075,043 of newly issued SPH Notes (with an aggregate par value of $1,000,000) and $184,761 in cash to tendering Inergy noteholders pursuant to the Exchange Offers; (ii) $65,000 in cash to the Inergy noteholders for the consent payments pursuant to the consent solicitations; (iii) $590,027 of new Suburban common units (consisting of 14,201 common units), which will be distributed to Inergy and Inergy Sales, all but $5,942 (consisting of 143 common units) of which will subsequently be distributed by Inergy to its unitholders; and (iv) reduced by the $17,971 of cash received from Inergy on the Acquisition Date, pursuant to the Contribution Agreement (the cash consideration received from Inergy includes the $36,500 discussed above, and is net of amounts owed to Inergy by the Partnership at the Acquisition Date).

The Inergy Propane Acquisition is consistent with key elements of the Partnership’s strategy for operational growth, which is to focus on businesses with a relatively steady cash flow that will extend the Partnership’s presence in strategically attractive markets, complement its existing business segments or provide an opportunity to diversify its operations with other energy-related assets. For the year ended September 30, 2011, Inergy Propane sold approximately 325,600 gallons of propane and 39,000 gallons of fuel oil and refined fuels to its retail customers in 33 states.

The following presents unaudited pro forma combined financial information as if the Inergy Propane Acquisition had occurred on September 26, 2010, the first day of the Partnership’s 2011 fiscal year. The pro forma net income for the nine months ended June 25, 2011 has been revised to properly include the costs of the Inergy Propane Acquisition of $15,750:

	For the three months ended						For the nine months ended
	June 23, 2012			June 25, 2011			June 23, 2012		June 25, 2011
Revenues	$	307,679		$	373,168		$	1,582,831	$	1,919,357
Net (loss) income	$	(46,428	)	$	(53,043	)	$	61,759	$	187,868
(Loss) income per unit
Basic	$	(0.93	)	$	(1.07	)	$	1.24	$	3.78
Diluted	$	(0.93	)	$	(1.07	)	$	1.24	$	3.76

The unaudited pro forma combined financial information reflect Inergy Propane’s historical operating results after giving effect to adjustments directly attributable to the transaction that are expected to have a continuing effect. The unaudited pro forma combined financial information is not necessarily indicative of the results that would have occurred had the Inergy Propane Acquisition occurred on the date indicated nor is it necessarily indicative of future operating results.

In accordance with the Contribution Agreement, the Partnership and Inergy entered into a transition services agreement (the “TSA”) whereby Inergy will provide certain services to the Partnership. The principal services include general business continuity, information technology, accounting, tax and administrative services. Services under the TSA will be provided through the expiration of the term relating to each service or until such time as mutually agreed by the parties. Amounts associated with the services were not material.

20

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 3, 2012	By:	/s/ MICHAEL A. STIVALA
Date		Michael A. Stivala
		Chief Financial Officer
August 3, 2012	By:	/s/ MICHAEL A. KUGLIN
Date		Michael A. Kuglin
		Vice President and Chief Accounting Officer

21

EXHIBIT INDEX

Exhibit Number	Description of Documents
2.1 *	Contribution Agreement dated as of April 25, 2012, as amended as of June 15, 2012, July 6, 2012 and July 19, 2012, among Inergy, L.P., Inergy GP, LLC, Inergy Sales and Service, Inc. and Suburban Propane Partners, L.P. (Incorporated by reference to Exhibit 2.1 to the Partnership’s Current Reports on Form 8-K filed April 26, 2012, June 15, 2012, July 6, 2012 and July 19, 2012, respectively).
31.1	Certification of the President and Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
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.
32.2	Certification of the Chief Financial Officer Pursuant to 18 U.S.C. Section 1350 as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.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

* Previously filed with Form 10-Q

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 J. Dunn, Jr., 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 3, 2012	By:	/s/ MICHAEL J. DUNN, JR.
		Michael J. Dunn, Jr.
		President and Chief Executive Officer

EX-31.2

EXHIBIT 31.2

Certification of the Chief Financial 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 3, 2012	By:	/s/ MICHAEL A. STIVALA
		Michael A. Stivala
		Chief Financial 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 23, 2012 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael J. Dunn, Jr., 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 J. DUNN, JR.
	Michael J. Dunn, Jr.
	President and Chief Executive Officer
	August 3, 2012

EX-32.2

EXHIBIT 32.2

Certification of the Chief Financial 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 23, 2012 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael A. Stivala, Chief Financial 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
	Chief Financial Officer
	August 3, 2012

XML

Distributions of Available Cash (Details) (USD $)	9 Months Ended
	Jun. 23, 2012
Distributions of Available Cash (Details) [Abstract]
Distributions to its partners	45 days
Number of quarters	4
Declaration date of quarterly distribution	July 18, 2012
Quarterly distribution (in dollars per unit)	$ 0.8525
Common Unit distribution on an annualized basis (in dollars per unit)	$ 3.41
Distribution date of quarterly distribution	August 7, 2012
Date of record of quarterly distribution	July 31, 2012

XML

Basis of Presentation (Details)	9 Months Ended
	Jun. 23, 2012
Basis of Presentation [Abstract]
Limited partner interest in the Operating Partnership	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
Period within which deferred revenue to be recognized on a straight line basis	1 year

XML

Inventories (Tables)

9 Months Ended

Jun. 23, 2012

Inventories [Abstract]

Schedule of inventory

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 23,		September 24,
	2012		2011
Propane, fuel oil and refined fuels and natural gas	$	50,969	$	64,601
Appliances and related parts		1,362		1,306
	$	52,331	$	65,907

XML

Guarantees (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Jun. 23, 2012
Guarantees [Abstract]
Transportation equipment remaining lease periods	2019
Maximum potential amount of aggregate future payments Partnership could be required to make	$ 10,119

XML

Net Income Per Common Unit (Details) In Thousands, unless otherwise specified	9 Months Ended
	Jun. 23, 2012	Jun. 25, 2011
Net Income Per Common Unit [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)	177,431	194,668

XML

Financial Instruments and Risk Management

9 Months Ended

Jun. 23, 2012

Financial Instruments and Risk Management [Abstract]

Financial Instruments and Risk Management

3. 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 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 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 options contracts and, in certain instances, over-the-counter options contracts (collectively, "derivative instruments") to hedge price risk associated with propane and fuel oil physical inventories, as well as anticipated future purchases of propane or fuel oil to be used in its operations and to ensure adequate supply during periods of high demand. 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. 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 futures, options and forward contracts 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, 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  ¹/₂ 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. 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 (Level 1 inputs), 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 gross fair value of the Partnership's derivative instruments and their location in the condensed consolidated balance sheet as of June 23, 2012 and September 24, 2011, respectively:

	As of June 23, 2012			As of September 24, 2011
Asset Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity options	Other current assets	$	7,263	Other current assets	$	3,710
	Other assets		-	Other assets		612
Commodity futures	Other current assets		1,952	Other current assets		1,132
		$	9,215		$	5,454
Liability Derivatives	Location	Fair Value		Location	Fair Value
Derivatives designated as hedging instruments:
Interest rate swaps	Other current liabilities	$	2,646	Other current liabilities	$	2,662
	Other liabilities		2,176	Other liabilities		1,934
		$	4,822		$	4,596
Derivatives not designated as hedging instruments:
Commodity options	Other current liabilities	$	1,338	Other current liabilities	$	2,407
	Other liabilities		-	Other liabilities		69
		$	1,338		$	2,476

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 June 23, 2012						Nine Months Ended June 25, 2011
	Assets			Liabilities			Assets			Liabilities
Opening balance of over-the-counter options	$	1,780		$	118		$	1,509		$	29
Beginning balance realized during the period		(758	)		(15	)		(1,509	)		(29	)
Contracts purchased during the period		3,245			259			2,778			226
Change in the fair value of beginning balance		2,678			669			-			-
Closing balance of over-the-counter options	$	6,945		$	1,031		$	2,778		$	226

As of June 23, 2012 and September 24, 2011, the Partnership's outstanding commodity-related derivatives had a weighted average maturity of approximately 3 months and 4 months, respectively.

The effect of the Partnership's derivative instruments on the condensed consolidated statements of operations for the three and nine months ended June 23, 2012 and June 25, 2011 are as follows:

	Three months ended June 23, 2012								Three months ended June 25, 2011
Derivatives in Cash Flow Hedging	Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)					Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)
Relationships	(Effective Portion)			Location		Amount			(Effective Portion)			Location		Amount
Interest rate swap	$	(1,856	)		Interest expense	$	(670	)	$	(1,077	)		Interest expense	$	(719	)
	$	(1,856	)			$	(670	)	$	(1,077	)			$	(719	)

Derivatives Not Designated as Hedging Instruments	Location of Gains (Losses)  Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income		Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income
Commodity options	Cost of products sold	$	6,465	Cost of products sold	$	(516	)
Commodity futures	Cost of products sold		1,753	Cost of products sold		203
		$	8,218		$	(313	)

	Nine months ended June 23, 2012							Nine months ended June 25, 2011
Derivatives in Cash Flow Hedging	Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)				Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)
Relationships	(Effective Portion)			Location	Amount			(Effective Portion)			Location	Amount
Interest rate swap	$	(2,234	)	Interest expense	$	(2,008	)	$	(851	)	Interest expense	$	(2,147	)
	$	(2,234	)		$	(2,008	)	$	(851	)		$	(2,147	)

Derivatives Not Designated as Hedging Instruments	Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income		Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income
Commodity options	Cost of products sold	$	6,350	Cost of products sold	$	283
Commodity futures	Cost of products sold		820	Cost of products sold		1,954
		$	7,170		$	2,237

Bank Debt and Senior Notes. The fair value of the Revolving Credit Facility (defined below) approximates the carrying value since the interest rates are periodically adjusted to reflect market conditions. Based upon quoted market prices, qualifying as a Level 1 fair value input, the fair value of the Partnership's 2020 senior notes was $262,500 and $248,500 as of June 23, 2012 and September 24, 2011, respectively.

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Pension Plans and Other Postretirement Benefits (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Jun. 23, 2012	Jun. 25, 2011	Jun. 23, 2012	Jun. 25, 2011
Defined Benefit Plan Disclosure [Line Items]
Projected annual contribution requirements related to the Partnership's postretirement health care and life insurance benefit plan for fiscal year	$ 0		$ 0
Contributions made related to the Partnership's postretirement health care and life insurance plan during the period	1,669		1,062
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost	1,577	1,706	4,733	5,117
Expected return on plan assets	(1,416)	(1,574)	(4,249)	(4,721)
Recognized net actuarial loss	1,318	1,180	3,953	3,540
Net periodic benefit cost	1,479	1,312	4,437	3,936
Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service Cost	2	2	5	6
Interest cost	200	214	602	641
Amortization of prior service costs	(122)	(122)	(367)	(367)
Recognized net actuarial loss	0	(9)	0	(27)
Net periodic benefit cost	$ 80	$ 85	$ 240	$ 253

XML

Pension Plans and Other Postretirement Benefits (Tables)

9 Months Ended

Jun. 23, 2012

Pension Plans and Other Postretirement Benefits [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 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Interest cost	$	1,577		$	1,706		$	4,733		$	5,117
Expected return on plan assets		(1,416	)		(1,574	)		(4,249	)		(4,721	)
Recognized net actuarial loss		1,318			1,180			3,953			3,540
Net periodic benefit cost	$	1,479		$	1,312		$	4,437		$	3,936

	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	June 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Service cost	$	2		$	2		$	5		$	6
Interest cost		200			214			602			641
Amortization of prior service costs		(122	)		(122	)		(367	)		(367	)
Recognized net actuarial loss		-			(9	)		-			(27	)
Net periodic benefit cost	$	80		$	85		$	240		$	253

XML

Unit-Based Compensation Arrangements (Tables)

9 Months Ended

Jun. 23, 2012

Unit-Based Compensation Arrangements [Abstract]

Summary of activity for the Restricted Unit Plans

During the nine months ended June 23, 2012, the Partnership awarded 108,674 restricted units under the Restricted Unit Plans at an aggregate grant date fair value of $3,543. The following is a summary of activity for the Restricted Unit Plans for the nine months ended June 23, 2012:

				Weighted
				Average Grant
				Date Fair Value
	Units			Per Unit
Outstanding September 24, 2011		485,423		$	32.71
Awarded		108,674			32.60
Forfeited		(11,093	)		(30.63	)
Issued		(115,911	)		(31.77	)
Outstanding June 23, 2012		467,093		$	33.04

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Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Jun. 23, 2012	Jun. 25, 2011	Jun. 23, 2012	Jun. 25, 2011	Sep. 24, 2011
Segment Information [Abstract]
Number of operating segments	5		5
Number of reportable segments	3		3
Segment Reporting Information [Line Items]
Total revenues	$ 179,601	$ 216,563	$ 837,113	$ 1,008,972
Total operating income	(2,744)	353	83,671	157,927
Reconciliation to net income [Abstract]
Loss on debt extinguishment	0	0	507	0
Interest expense, net	6,479	6,867	19,742	20,532
Provision for income taxes	100	273	(60)	737
Net income	(9,323)	(6,787)	63,482	136,658
Total depreciation and amortization	8,472	9,670	23,906	26,304
Total assets	896,064		896,064		956,459
All other [Member]
Segment Reporting Information [Line Items]
Total revenues	7,268	8,086	26,177	29,208
Total operating income	(4,029)	(3,433)	(10,358)	(8,947)
Reconciliation to net income [Abstract]
Total depreciation and amortization	19	34	72	192
Total assets	3,693		3,693		3,719
Corporate [Member]
Segment Reporting Information [Line Items]
Total operating income	(23,612)	(18,119)	(55,123)	(51,672)
Reconciliation to net income [Abstract]
Total depreciation and amortization	1,799	3,022	5,860	7,423
Total assets	153,431		153,431		183,084
Propane [Member]
Segment Reporting Information [Line Items]
Total revenues	142,681	169,258	666,796	786,968
Total operating income	25,270	20,434	139,251	193,700
Reconciliation to net income [Abstract]
Total depreciation and amortization	5,142	5,011	14,997	15,326
Total assets	685,576		685,576		706,008
Fuel oil and refined fuels [Member]
Segment Reporting Information [Line Items]
Total revenues	17,533	22,528	92,262	124,448
Total operating income	(1,789)	(318)	4,142	14,437
Reconciliation to net income [Abstract]
Total depreciation and amortization	1,433	1,378	2,595	2,691
Total assets	38,765		38,765		44,973
Natural gas and electricity [Member]
Segment Reporting Information [Line Items]
Total revenues	12,119	16,691	51,878	68,348
Total operating income	1,416	1,789	5,759	10,409
Reconciliation to net income [Abstract]
Total depreciation and amortization	79	225	382	672
Total assets	$ 14,599		$ 14,599		$ 18,675

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Segment Information (Tables)

9 Months Ended

Jun. 23, 2012

Segment Information [Abstract]

Certain data by reportable segment and a reconciliation of total operating segment information to the corresponding consolidated amounts for the periods presented

The following table presents certain relevant financial information 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 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Revenues:
Propane	$	142,681		$	169,258		$	666,796		$	786,968
Fuel oil and refined fuels		17,533			22,528			92,262			124,448
Natural gas and electricity		12,119			16,691			51,878			68,348
All other		7,268			8,086			26,177			29,208
Total revenues	$	179,601		$	216,563		$	837,113		$	1,008,972
Operating income:
Propane	$	25,270		$	20,434		$	139,251		$	193,700
Fuel oil and refined fuels		(1,789	)		(318	)		4,142			14,437
Natural gas and electricity		1,416			1,789			5,759			10,409
All other		(4,029	)		(3,433	)		(10,358	)		(8,947	)
Corporate		(23,612	)		(18,119	)		(55,123	)		(51,672	)
Total operating income		(2,744	)		353			83,671			157,927
Reconciliation to net income:
Loss on debt extinguishment		-			-			507			-
Interest expense, net		6,479			6,867			19,742			20,532
Provision for income taxes		100			273			(60	)		737
Net income	$	(9,323	)	$	(6,787	)	$	63,482		$	136,658
Depreciation and amortization:
Propane	$	5,142		$	5,011		$	14,997		$	15,326
Fuel oil and refined fuels		1,433			1,378			2,595			2,691
Natural gas and electricity		79			225			382			672
All other		19			34			72			192
Corporate		1,799			3,022			5,860			7,423
Total depreciation and amortization	$	8,472		$	9,670		$	23,906		$	26,304

	As of
	June 23, 2012		September 24, 2011
Assets:
Propane	$	685,576	$	706,008
Fuel oil and refined fuels		38,765		44,973
Natural gas and electricity		14,599		18,675
All other		3,693		3,719
Corporate		153,431		183,084
Total assets	$	896,064	$	956,459

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Subsequent Events (Tables)

9 Months Ended

Jun. 23, 2012

Subsequent Events [Abstract]

Unaudited pro forma combined financial information

The following presents unaudited pro forma combined financial information as if the Inergy Propane Acquisition had occurred on September 26, 2010, the first day of the Partnership's 2011 fiscal year. The pro forma net income for the nine months ended June 25, 2011 has been amended to properly include the costs of the Inergy Propane Acquisition of $15,750:

	For the three months ended						For the nine months ended
	June 23, 2012			June 25, 2011			June 23, 2012		June 25, 2011
Revenues	$	307,679		$	373,168		$	1,582,831	$	1,919,357
Net (loss) income	$	(46,428	)	$	(53,043	)	$	61,759	$	187,868
(Loss) income per unit
Basic	$	(0.93	)	$	(1.07	)	$	1.24	$	3.78
Diluted	$	(0.93	)	$	(1.07	)	$	1.24	$	3.76

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Basis of Presentation

9 Months Ended

Jun. 23, 2012

Basis of Presentation [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 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 24, 2011. 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 13 weeks in duration. When the Partnership's fiscal year is 53 weeks long, the corresponding fourth quarter is 14 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 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 billing 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.

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 depreciation and amortization of long-lived assets, insurance and litigation reserves, severance benefits, pension and other postretirement benefit liabilities and costs, purchase accounting, valuation of derivative instruments, asset valuation assessments, tax valuation allowances, as well as the allowance for doubtful accounts. Actual results could differ from those estimates, making it reasonably possible that a change in these estimates could occur in the near term.

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Partnership Organization and Formation (Details)	Jun. 23, 2012	Sep. 24, 2011
Fiscal Period [Abstract]
Common Units outstanding (in units)	35,545,000	35,429,000
Percentage of wholly-owned subsidiary (in hundredths)	100.00%
General Partner [Member] | Common Unitholders [Member]
Fiscal Period [Abstract]
Common Units outstanding (in units)	784

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Unit-Based Compensation Arrangements (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Jun. 23, 2012	Jun. 25, 2011	Jun. 23, 2012	Jun. 25, 2011	Sep. 24, 2011
Units [Rollforward]
Outstanding September 24, 2011 (in units)			485,423
Awarded (in units)			108,674
Forfeited (in units)			(11,093)
Issued (in units)			(115,911)
Outstanding June 23, 2012 (in units)	467,093		467,093
Weighted Average Grant Date Fair Value Per Unit [Abstract]
Outstanding September 24, 2011 (in dollars per unit)			$ 32.71
Awarded (in dollars per unit)			$ 32.60
Forfeited (in dollars per unit)	$ (30.63)		$ (30.63)
Issued (in dollars per unit)			$ (31.77)
Outstanding June 23, 2012 (in dollars per unit)	$ 33.04		$ 33.04
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Total number of Common Units authorized for issuance under the Restricted Unit Plans	1,902,122		1,902,122
Restricted Unit Plans, terms of award			Unless otherwise stipulated by the Compensation Committee of the Board of Supervisors on or before the grant date, restricted units issued under the Restricted Unit Plans vest over time with 25% of the Common Units vesting on each of the third and fourth anniversaries of the grant date and the remaining 50% of the Common Units vesting on the fifth anniversary of the grant date. The Restricted Unit Plans participants are not eligible to receive quarterly distributions with respect to or vote their respective restricted units until vested. Because each restricted unit represents a promise to issue a Common Unit at a future date, restricted units cannot be sold or transferred prior to vesting.
Aggregate grant date fair value of restricted units awarded			$ 3,543
Unrecognized compensation cost related to unvested restricted units awarded under the Restricted Unit Plans	6,264		6,264
Weighted-average period over which compensation cost associated with unvested awards is expected to be recognized (in years)			1.8
Compensation expense - Restricted Unit Plans (RUP)	911	737	3,261	3,136
Long-Term Incentive Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Long-Term incentive Plan, terms of award			The Partnership has a non-qualified, unfunded long-term incentive plan for officers and key employees (the "LTIP") which provides for payment, in the form of cash, of an award of equity-based compensation at the end of a three-year performance period.
Compensation expense - Long-Term Incentive Plan (LTIP)	(49)	31	643	1,532
Liability included within accrued employment and benefit costs (or other liabilities, as applicable) related to estimated future payments under the LTIP	$ 2,471		$ 2,471		$ 5,164

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $) In Thousands, unless otherwise specified	Jun. 23, 2012	Sep. 24, 2011
Current assets:
Cash and cash equivalents	$ 115,804	$ 149,553
Accounts receivable, less allowance for doubtful accounts of $5,990 and $6,960, respectively	62,478	66,630
Inventories	52,331	65,907
Other current assets	18,555	15,732
Total current assets	249,168	297,822
Property, plant and equipment, net	327,212	338,125
Goodwill	277,651	277,651
Other assets	42,033	42,861
Total assets	896,064	956,459
Current liabilities:
Accounts payable	26,309	37,456
Accrued employment and benefit costs	12,371	22,951
Customer deposits and advances	36,634	57,476
Other current liabilities	35,770	33,631
Total current liabilities	111,084	151,514
Long-term borrowings	348,331	348,169
Accrued insurance	43,604	42,891
Other liabilities	55,515	55,667
Total liabilities	558,534	598,241
Partners' capital:
Common Unitholders (35,545 and 35,429 units issued and outstanding at June 23, 2012 and September 24, 2011, respectively)	394,086	418,134
Accumulated other comprehensive loss	(56,556)	(59,916)
Total partners' capital	337,530	358,218
Total liabilities and partners' capital	$ 896,064	$ 956,459

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Subsequent Events (Details) (USD $) In Thousands, except Share data, unless otherwise specified	0 Months Ended	3 Months Ended		9 Months Ended		12 Months Ended		0 Months Ended			0 Months Ended
	Aug. 01, 2012 Acquisition [Member] Inergy Propane LLC [Member]	Jun. 23, 2012 Acquisition [Member] Inergy Propane LLC [Member]	Jun. 25, 2011 Acquisition [Member] Inergy Propane LLC [Member]	Jun. 23, 2012 Acquisition [Member] Inergy Propane LLC [Member]	Jun. 25, 2011 Acquisition [Member] Inergy Propane LLC [Member]	Sep. 30, 2011 Acquisition [Member] Inergy Propane LLC [Member] gal	Aug. 01, 2012 Acquisition [Member] Inergy Propane LLC [Member] Inergy Notes [Member]	Aug. 01, 2012 Acquisition [Member] Inergy Propane LLC [Member] Inergy Senior Notes due 2018 [Member]	Aug. 01, 2012 Acquisition [Member] Inergy Propane LLC [Member] Inergy Senior Notes due 2021 [Member]	Aug. 01, 2012 Acquisition [Member] Inergy Propane LLC [Member] SPH Notes [Member]	Aug. 01, 2012 Acquisition [Member] Inergy Propane LLC [Member] SPH Senior Notes due 2018 [Member]	Aug. 01, 2012 Acquisition [Member] Inergy Propane LLC [Member] SPH Senior Notes due 2021 [Member]	Mar. 21, 2015 Financing [Member] Amended Credit Agreement [Member]	Aug. 01, 2012 Financing [Member] Amended Credit Agreement [Member]	Aug. 01, 2012 Financing [Member] Amended Credit Agreement [Member] Term Loan Facility [Member]	Aug. 01, 2012 Financing [Member] Amended Credit Agreement [Member] Revolving Credit Facility [Member]	Jul. 31, 2012 Financing [Member] Amended Credit Agreement [Member] Revolving Credit Facility [Member]
Subsequent Event [Line Items]
New common units issued as part of an acquisition	$ 600,000
Number of trading days	20 days
Average sales price of common units (in dollars per unit)	$ 43.1885
New common units issued as part of an acquisition (in units)	13,893
Stated interest rate (in hundredths)								7.00%	6.875%		7.50%	7.375%
Year of maturity of debt instrument								2018	2021		2018	2021
Aggregate principal amount							1,200,000			1,000,000
Maximum potential cash payment to tendering noteholders as part of an acquisition	200,000
Aggregate cash consent payments to acquiree in connection with note exchange	65,000
Cash paid by acquiree to Partnership	36,500
Outstanding principal amount for which tenders and consents had been received (in hundredths)								98.09%	99.74%
Equity Exchange Cash Consideration due to tendering noteholders in connection with note exchange	184,761
Common units issued in satisfaction of Inergy Cash Consideration (in units)	308
Total common units issued to acquiree, including units issued in connection with note exchange (in units)	14,201
Common units to be distributed by acquiree to its unitholders (in units)	14,058
Total common units retained by the acquiree (in hundredths)	1.00%
Total common units retained by the acquiree (in units)	143
Maximum borrowing capacity															250,000	400,000	250,000
Term of facility															364 days
Amount drawn on facility															225,000
Minimum consolidated interest coverage ratio													2.5 to 1.0	2.0 to 1.0
Maximum consolidated leverage ratio													4.75 to 1.0	7.0 to 1.0
Total acquisition value	1,896,860
Aggregate amount of newly issued SPH notes										1,075,043
Total new common units issued as part of an acquisition	590,027
Total common units retained by the acquiree	5,942
Cash paid by acquiree to Partnership, net of amounts owed to acquiree by Partnership	17,971
Propane sold by acquiree (in gallons)						325,600
Fuel oil and refined fuels sold by acquiree (in gallons)						39,000
Number of states in which the acquiree had retail customers	33
Costs of the Inergy Propane Acquisition					15,750
Unaudited pro forma combined financial information [Abstract]
Revenues		307,679	373,168	1,582,831	1,919,357
Net (loss) income		$ (46,428)	$ (53,043)	$ 61,759	$ 187,868
(Loss) income per unit, basic (in dollars per share)		$ (0.93)	$ (1.07)	$ 1.24	$ 3.78
(Loss) income per unit, diluted (in dollars per share)		$ (0.93)	$ (1.07)	$ 1.24	$ 3.76

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CONDENSED CONSOLIDATED STATEMENT OF PARTNERS' CAPITAL (Unaudited) (USD $) In Thousands, unless otherwise specified	Common Unitholders [Member]	Accumulated Other Comprehensive (Loss) [Member]	Total	Comprehensive Income [Member]
Balance at Sep. 24, 2011	$ 418,134	$ (59,916)	$ 358,218
Balance (in units) at Sep. 24, 2011	35,429
Net income	63,482		63,482	63,482
Other comprehensive income:
Unrealized losses on cash flow hedges		(2,234)	(2,234)	(2,234)
Reclassification of realized losses on cash flow hedges into earnings		2,008	2,008	2,008
Amortization of net actuarial losses and prior service credits into earnings		3,586	3,586	3,586
Comprehensive income				66,842
Partnership distributions	(90,790)		(90,790)
Common Units issued under Restricted Unit Plans (in units)	116
Compensation cost recognized under Restricted Unit Plans, net of forfeitures	3,260		3,260
Balance at Jun. 23, 2012	$ 394,086	$ (56,556)	$ 337,530
Balance (in units) at Jun. 23, 2012	35,545

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Inventories (Details) (USD $) In Thousands, unless otherwise specified	Jun. 23, 2012	Sep. 24, 2011
Summary of inventory [Abstract]
Propane, fuel oil and refined fuels and natural gas	$ 50,969	$ 64,601
Appliances and related parts	1,362	1,306
Inventories	$ 52,331	$ 65,907

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Subsequent Events

9 Months Ended

Jun. 23, 2012

Subsequent Events [Abstract]

Subsequent Events

16. Subsequent Event - Acquisition of Inergy Propane

On August 1, 2012 (the "Acquisition Date"), the Partnership completed the acquisition of the sole membership interest in Inergy Propane, LLC, including certain wholly-owned subsidiaries of Inergy Propane LLC, and the assets of Inergy Sales and Service, Inc. ("Inergy Sales"). The acquired interests and assets are collectively referred to as "Inergy Propane." As of the Acquisition Date, Inergy Propane consisted of the former retail propane assets and operations of Inergy, L.P. ("Inergy").

The acquisition of Inergy Propane (the "Inergy Propane Acquisition") was consummated pursuant to a definitive agreement dated April 25, 2012 with Inergy, Inergy GP, LLC and Inergy Sales, as amended (the "Contribution Agreement"). Prior to the Acquisition Date, Inergy Propane transferred its interest in certain subsidiaries, as well as all of its rights and interests in the assets and properties of its wholesale propane supply, marketing and distribution business, and its rights and interest in the assets and properties of its West Coast natural gas liquids business, to Inergy. These assets were not included as part of the Inergy Propane business at the time of the transfer of the membership interests in Inergy Propane to the Partnership and were not part of the Inergy Propane Acquisition. On the Acquisition Date, Inergy Propane and its remaining wholly-owned subsidiaries acquired became subsidiaries of the Partnership. The results of operations of Inergy Propane will be included in the Partnership's results of operations beginning on the Acquisition Date.

Pursuant to the Contribution Agreement, the Partnership agreed to issue $600,000 in new common units in the aggregate to Inergy and Inergy Sales (the "Equity Consideration"). In accordance with the Contribution Agreement, the number of common units to be issued to Inergy and Inergy Sales in the aggregate is determined by dividing $600,000 by the average of the high and low sales prices of the Partnership's common units for the twenty consecutive trading days ending on the day prior to the execution of the Contribution Agreement, which was determined to be $43.1885, resulting in 13,893 common units.

Also pursuant to the Contribution Agreement, the Partnership and its wholly-owned subsidiary Suburban Energy Finance Corp. commenced an offer to exchange (the "Exchange Offers") any and all of the outstanding unsecured 7% Senior Notes due 2018 and 6 ⁷/8% Senior Notes due 2021 issued by Inergy and Inergy Finance Corp., which had an aggregate principal amount outstanding of $1,200,000 (collectively, the "Inergy Notes"), for a combination of $1,000,000 in aggregate principal amount of new unsecured 7 ¹/2% Senior Notes due 2018 and 7 ³/8% Senior Notes due 2021 (collectively, the "SPH Notes") issued by the Partnership and Suburban Energy Finance Corp. and up to $200,000 in cash to be paid to tendering noteholders (the "Exchange Offer Cash Consideration"). Pursuant to the Contribution Agreement, the Partnership was required to pay Inergy the difference, if any, between $200,000 and the actual Exchange Offer Cash Consideration paid in accordance with the terms of the Exchange Offers (such payment, the "Inergy Cash Consideration"). The Contribution Agreement provides that the Partnership will offer $65,000 in aggregate cash consent payments in connection with the Exchange Offers and that Inergy will pay $36,500 to the Partnership in cash on the Acquisition Date. The Exchange Offers expired and settled on August 1, 2012 (the "Settlement Date"). On the Settlement Date, the Partnership had received tenders and consents from holders representing approximately 98.09% of the total outstanding principal amount of the 2018 Inergy Notes, and tenders and consents from holders representing approximately 99.74% of the total outstanding principal amount of the 2021 Inergy Notes. Based on the results of the Exchange Offers, the Exchange Offer Cash Consideration due to tendering Inergy noteholders was $184,761. The Inergy Cash Consideration was satisfied by the issuance of 308 common units to Inergy and therefore, when combined with the Equity Consideration, the Partnership issued 14,201 common units in the aggregate to Inergy and Inergy Sales on August 1, 2012. Inergy will subsequently distribute 14,058 of such common units to its unitholders and will retain 1% of such common units, or 143 common units.

On April 25, 2012, the Partnership received consents from the requisite lenders under the Amended Credit Agreement to enable it to incur additional indebtedness, make amendments to the Amended Credit Agreement to adjust certain covenants, and otherwise perform our obligations as contemplated by the Inergy Propane Acquisition. On August 1, 2012, the Operating Partnership executed an amendment to the Amended Credit Agreement to, among other things, provide for (i) a $250,000 senior secured 364-day incremental term loan facility (the "364-Day Facility") and (ii) an increase in our revolving credit facility under the Amended Credit Agreement from $250,000 to $400,000. On the Acquisition Date, the Operating Partnership drew $225,000 on the 364-Day Facility, which, together with cash received from Inergy (pursuant to the Contribution Agreement) and cash on hand, was used to pay (i) the consent fees and the Exchange Offer Cash Consideration, (ii) costs and fees related to the Exchange Offers, and (iii) costs and expenses related to the Inergy Propane Acquisition. The Partnership intends to repay such borrowings with an equity financing in the future, subject to market conditions.

The amendment to the Amended Credit Agreement also amended certain restrictive and affirmative covenants applicable to the Operating Partnership and the Partnership, as well as certain financial covenants, including (a) requiring the Partnership's consolidated interest coverage ratio, as defined in the amendment, to be not less than 2.0 to 1.0 as of the end of any fiscal quarter; (b) prohibiting the total consolidated leverage ratio, as defined in the amendment, of the Partnership from being greater than 7.0 to 1.0 as of the end of any fiscal quarter. The minimum consolidated interest coverage ratio increases over time, and commencing with the second quarter of fiscal 2015, such minimum ratio will be 2.5 to 1.0. The maximum consolidated leverage ratio decreases over time, and commencing with the first quarter of fiscal 2015, such maximum ratio will be 4.75 to 1.0.

The preliminary fair value of the purchase price for Inergy Propane was $1,896,860, consisting of: (i) $1,075,043 of newly issued SPH Notes (with an aggregate par value of $1,000,000) and $184,761 in cash to tendering Inergy noteholders pursuant to the Exchange Offers; (ii) $65,000 in cash to the Inergy noteholders for the consent payments pursuant to the consent solicitations; (iii) $590,027 of new Suburban common units (consisting of 14,201 common units), which will be distributed to Inergy and Inergy Sales, all but $5,942 (consisting of 143 common units) of which will subsequently be distributed by Inergy to its unitholders; and (iv) reduced by the $17,971 of cash received from Inergy on the Acquisition Date, pursuant to the Contribution Agreement (the cash consideration received from Inergy includes the $36,500 discussed above and is net of amounts owed to Inergy by the Partnership at the Acquisition Date).

The Inergy Propane Acquisition is consistent with key elements of the Partnership's strategy for operational growth, which is to focus on businesses with a relatively steady cash flow that will extend the Partnership's presence in strategically attractive markets, complement its existing business segments or provide an opportunity to diversify its operations with other energy-related assets. For the year ended September 30, 2011, Inergy Propane sold approximately 325,600 gallons of propane and 39,000 gallons of fuel oil and refined fuels to its retail customers in 33 states.

The following presents unaudited pro forma combined financial information as if the Inergy Propane Acquisition had occurred on September 26, 2010, the first day of the Partnership's 2011 fiscal year. The pro forma net income for the nine months ended June 25, 2011 has been amended to properly include the costs of the Inergy Propane Acquisition of $15,750:

	For the three months ended						For the nine months ended
	June 23, 2012			June 25, 2011			June 23, 2012		June 25, 2011
Revenues	$	307,679		$	373,168		$	1,582,831	$	1,919,357
Net (loss) income	$	(46,428	)	$	(53,043	)	$	61,759	$	187,868
(Loss) income per unit
Basic	$	(0.93	)	$	(1.07	)	$	1.24	$	3.78
Diluted	$	(0.93	)	$	(1.07	)	$	1.24	$	3.76

The unaudited pro forma combined financial information reflect Inergy Propane's historical operating results after giving effect to adjustments directly attributable to the transaction that are expected to have a continuing effect. The unaudited pro forma combined financial information is not necessarily indicative of the results that would have occurred had the Inergy Propane Acquisition occurred on the date indicated nor is it necessarily indicative of future operating results.

In accordance with the Contribution Agreement, the Partnership and Inergy entered into a transition services agreement (the "TSA") whereby Inergy will provide certain services to the Partnership. The principal services include general business continuity, information technology, accounting, tax and administrative services. Services under the TSA will be provided through the expiration of the term relating to each service or until such time as mutually agreed by the parties. Amounts associated with the services were not material.

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Goodwill (Details) (USD $) In Thousands, unless otherwise specified	Jun. 23, 2012	Sep. 24, 2011
Goodwill [Abstract]
Projection period for discounted cash flow analyses to estimate reporting unit fair value	10 years
Goodwill [Line Items]
Goodwill	$ 277,651	$ 277,651
Propane [Member]
Goodwill [Line Items]
Goodwill	265,313	265,313
Fuel oil and refined fuels [Member]
Goodwill [Line Items]
Goodwill	4,438	4,438
Natural gas and electricity [Member]
Goodwill [Line Items]
Goodwill	$ 7,900	$ 7,900

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Financial Instruments and Risk Management (Tables)

9 Months Ended

Jun. 23, 2012

Financial Instruments and Risk Management [Abstract]

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

The following summarizes the gross fair value of the Partnership's derivative instruments and their location in the condensed consolidated balance sheet as of June 23, 2012 and September 24, 2011, respectively:

	As of June 23, 2012			As of September 24, 2011
Asset Derivatives	Location	Fair Value		Location	Fair Value
Derivatives not designated as hedging instruments:
Commodity options	Other current assets	$	7,263	Other current assets	$	3,710
	Other assets		-	Other assets		612
Commodity futures	Other current assets		1,952	Other current assets		1,132
		$	9,215		$	5,454
Liability Derivatives	Location	Fair Value		Location	Fair Value
Derivatives designated as hedging instruments:
Interest rate swaps	Other current liabilities	$	2,646	Other current liabilities	$	2,662
	Other liabilities		2,176	Other liabilities		1,934
		$	4,822		$	4,596
Derivatives not designated as hedging instruments:
Commodity options	Other current liabilities	$	1,338	Other current liabilities	$	2,407
	Other liabilities		-	Other liabilities		69
		$	1,338		$	2,476

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 June 23, 2012						Nine Months Ended June 25, 2011
	Assets			Liabilities			Assets			Liabilities
Opening balance of over-the-counter options	$	1,780		$	118		$	1,509		$	29
Beginning balance realized during the period		(758	)		(15	)		(1,509	)		(29	)
Contracts purchased during the period		3,245			259			2,778			226
Change in the fair value of beginning balance		2,678			669			-			-
Closing balance of over-the-counter options	$	6,945		$	1,031		$	2,778		$	226

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 for the three and nine months ended June 23, 2012 and June 25, 2011 are as follows:

	Three months ended June 23, 2012								Three months ended June 25, 2011
Derivatives in Cash Flow Hedging	Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)					Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)
Relationships	(Effective Portion)			Location		Amount			(Effective Portion)			Location		Amount
Interest rate swap	$	(1,856	)		Interest expense	$	(670	)	$	(1,077	)		Interest expense	$	(719	)
	$	(1,856	)			$	(670	)	$	(1,077	)			$	(719	)

Derivatives Not Designated as Hedging Instruments	Location of Gains (Losses)  Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income		Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income
Commodity options	Cost of products sold	$	6,465	Cost of products sold	$	(516	)
Commodity futures	Cost of products sold		1,753	Cost of products sold		203
		$	8,218		$	(313	)

	Nine months ended June 23, 2012							Nine months ended June 25, 2011
Derivatives in Cash Flow Hedging	Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)				Gains (Losses) Recognized in OCI			Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)
Relationships	(Effective Portion)			Location	Amount			(Effective Portion)			Location	Amount
Interest rate swap	$	(2,234	)	Interest expense	$	(2,008	)	$	(851	)	Interest expense	$	(2,147	)
	$	(2,234	)		$	(2,008	)	$	(851	)		$	(2,147	)

Derivatives Not Designated as Hedging Instruments	Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income		Location of Gains (Losses) Recognized in Income	Amount of Unrealized Gains (Losses) Recognized in Income
Commodity options	Cost of products sold	$	6,350	Cost of products sold	$	283
Commodity futures	Cost of products sold		820	Cost of products sold		1,954
		$	7,170		$	2,237

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Partnership Organization and Formation

9 Months Ended

Jun. 23, 2012

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 35,544,766 Common Units outstanding at June 23, 2012. 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 corporate entities (collectively referred to as the "Corporate Entities") and, as such, are subject to corporate level federal and state income tax.

Suburban Energy Finance Corporation, 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.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) (USD $) In Thousands, unless otherwise specified	Jun. 23, 2012	Sep. 24, 2011
Current assets:
Allowance for doubtful accounts	$ 5,990	$ 6,960
Partner's capital:
Common units issued (in units)	35,545	35,429
Common units outstanding (in units)	35,545	35,429

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Guarantees

9 Months Ended

Jun. 23, 2012

Guarantees [Abstract]

Guarantees

11. 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 2019. 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 $10,119 as of June 23, 2012. The fair value of residual value guarantees for outstanding operating leases was de minimis as of June 23, 2012 and September 24, 2011.

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Document and Entity Information	9 Months Ended
	Jun. 23, 2012
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 Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	35,544,766
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 23, 2012

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Pension Plans and Other Postretirement Benefits

9 Months Ended

Jun. 23, 2012

Pension Plans and Other Postretirement Benefits [Abstract]

Pension Plans and Other Postretirement Benefits

12. 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 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Interest cost	$	1,577		$	1,706		$	4,733		$	5,117
Expected return on plan assets		(1,416	)		(1,574	)		(4,249	)		(4,721	)
Recognized net actuarial loss		1,318			1,180			3,953			3,540
Net periodic benefit cost	$	1,479		$	1,312		$	4,437		$	3,936

	Postretirement Benefits
	Three Months Ended						Nine Months Ended
	June 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Service cost	$	2		$	2		$	5		$	6
Interest cost		200			214			602			641
Amortization of prior service costs		(122	)		(122	)		(367	)		(367	)
Recognized net actuarial loss		-			(9	)		-			(27	)
Net periodic benefit cost	$	80		$	85		$	240		$	253

There are no projected minimum employer cash contribution requirements under ERISA laws for fiscal 2012 under our defined benefit pension plan. The projected annual contribution requirements related to the Partnership's postretirement health care and life insurance benefit plan for fiscal 2012 is $1,669, of which $1,062 has been contributed during the nine months ended June 23, 2012.

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CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Jun. 23, 2012	Jun. 25, 2011	Jun. 23, 2012	Jun. 25, 2011
Revenues
Propane	$ 142,681	$ 169,258	$ 666,796	$ 786,968
Fuel oil and refined fuels	17,533	22,528	92,262	124,448
Natural gas and electricity	12,119	16,691	51,878	68,348
All other	7,268	8,086	26,177	29,208
Total Revenue	179,601	216,563	837,113	1,008,972
Costs and expenses
Cost of products sold	88,776	125,175	480,751	571,511
Operating	65,369	68,747	202,604	213,831
General and administrative	13,778	12,618	40,231	37,399
Severance charges	0	0	0	2,000
Acquisition-related costs	5,950	0	5,950	0
Depreciation and amortization	8,472	9,670	23,906	26,304
Total Expenses	182,345	216,210	753,442	851,045
Operating income	(2,744)	353	83,671	157,927
Loss on debt extinguishment	0	0	507	0
Interest expense, net	6,479	6,867	19,742	20,532
Income before (benefit from) provision for income taxes	(9,223)	(6,514)	63,422	137,395
(Benefit from) provision for income taxes	100	273	(60)	737
Net income	$ (9,323)	$ (6,787)	$ 63,482	$ 136,658
Income per Common Unit - basic	$ (0.26)	$ (0.19)	$ 1.78	$ 3.85
Weighted average number of Common Units outstanding - basic	35,653	35,540	35,616	35,517
Income per Common Unit - diluted	$ (0.26)	$ (0.19)	$ 1.77	$ 3.83
Weighted average number of Common Units outstanding - diluted	35,653	35,540	35,794	35,712

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Net Income Per Common Unit

9 Months Ended

Jun. 23, 2012

Net Income Per Common Unit [Abstract]

Net Income Per Common Unit

6. 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 restricted units granted under the restricted unit plans 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 unvested 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 177,431 and 194,668 units for the nine months ended June 23, 2012 and June 25, 2011, respectively, to reflect the potential dilutive effect of the unvested restricted units outstanding using the treasury stock method.

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Goodwill

9 Months Ended

Jun. 23, 2012

Goodwill [Abstract]

Goodwill

5. Goodwill

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 in August of each year, or when an event occurs or circumstances change that would indicate potential impairment. 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:

	As of
	June 23,		September 24,
	2012		2011
Propane	$	265,313	$	265,313
Fuel oil and refined fuels		4,438		4,438
Natural gas and electricity		7,900		7,900
	$	277,651	$	277,651

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Basis of Presentation (Policies)

9 Months Ended

Jun. 23, 2012

Basis of Presentation [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 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 24, 2011. 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 13 weeks in duration. When the Partnership's fiscal year is 53 weeks long, the corresponding fourth quarter is 14 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 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 billing 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.

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 depreciation and amortization of long-lived assets, insurance and litigation reserves, severance benefits, pension and other postretirement benefit liabilities and costs, purchase accounting, valuation of derivative instruments, asset valuation assessments, tax valuation allowances, as well as the allowance for doubtful accounts. Actual results could differ from those estimates, making it reasonably possible that a change in these estimates could occur in the near term.

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Income Taxes

9 Months Ended

Jun. 23, 2012

Income Taxes [Abstract]

Income Taxes

13. 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, as a separate legal entity, and the Operating Partnership are not subject to income tax at the Partnership level. Rather, the taxable income or loss attributable to the Partnership, as a separate legal entity, and to the Operating Partnership, which may vary substantially from the income 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 individual partners. 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 information regarding each partner'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 alternative minimum tax. A full valuation allowance has been provided against the deferred tax assets 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.

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Unit-Based Compensation Arrangements

9 Months Ended

Jun. 23, 2012

Unit-Based Compensation Arrangements [Abstract]

Unit-Based Compensation Arrangements

9. 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. In fiscal 2000 and fiscal 2009, the Partnership adopted the Suburban Propane Partners, L.P. 2000 Restricted Unit Plan and 2009 Restricted Unit Plan (collectively, the "Restricted Unit Plans"), respectively, which authorize 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 Restricted Unit Plans was 1,902,122 as of June 23, 2012. Unless otherwise stipulated by the Compensation Committee of the Board of Supervisors on or before the grant date, restricted units issued under the Restricted Unit Plans vest over time with 25% of the Common Units vesting on each of the third and fourth anniversaries of the grant date and the remaining 50% of the Common Units vesting on the fifth anniversary of the grant date. The Restricted Unit Plans participants are not eligible to receive quarterly distributions with respect to or vote their respective restricted units until vested. Because each restricted unit represents a promise to issue a Common Unit at a future date, restricted units cannot be sold or transferred prior to vesting. The fair 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 and forfeitures during the vesting period. Restricted units are subject to forfeiture in certain circumstances as defined in the Restricted Unit Plans. Compensation expense for the unvested awards is recognized ratably over the vesting periods and is net of estimated forfeitures.

During the nine months ended June 23, 2012, the Partnership awarded 108,674 restricted units under the Restricted Unit Plans at an aggregate grant date fair value of $3,543. The following is a summary of activity for the Restricted Unit Plans for the nine months ended June 23, 2012:

				Weighted
				Average Grant
				Date Fair Value
	Units			Per Unit
Outstanding September 24, 2011		485,423		$	32.71
Awarded		108,674			32.60
Forfeited		(11,093	)		(30.63	)
Issued		(115,911	)		(31.77	)
Outstanding June 23, 2012		467,093		$	33.04

As of June 23, 2012, unrecognized compensation cost related to unvested restricted units awarded under the Restricted Unit Plans amounted to $6,264. Compensation cost associated with unvested awards is expected to be recognized over a weighted-average period of 1.8 years. Compensation expense recognized under the Restricted Unit Plans, net of forfeitures, for the three and nine months ended June 23, 2012 was $911 and $3,261, respectively, and $737 and $3,136 for the three and nine months ended June 25, 2011, respectively. 

Long-Term Incentive Plan. The Partnership has a non-qualified, unfunded long-term incentive plan for officers and key employees (the "LTIP") which 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 market performance of the Partnership's Common Units on the basis of total return to Unitholders ("TRU") compared to the TRU of a predetermined peer group consisting solely of other master limited partnerships, approved by the Compensation Committee of the Board of Supervisors, over the same three-year performance period. 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 23, 2012 was $(49) and $643, respectively, and $31 and $1,532 for the three and nine months ended June 25, 2011, respectively. As of June 23, 2012 and September 24, 2011, the Partnership had a liability included within accrued employment and benefit costs (or other liabilities, as applicable) of $2,471 and $5,164, respectively, related to estimated future payments under the LTIP.

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Long Term Borrowings

9 Months Ended

Jun. 23, 2012

Long-Term Borrowings [Abstract]

Long Term Borrowings

7. Long-Term Borrowings

Long-term borrowings consist of the following:

	As of
	June 23,		September 24,
	2012		2011
7.375% senior notes, due March 15, 2020, net of unamortized discount of $1,669 and $1,831, respectively	$	248,331	$	248,169
Revolving credit facility, due January 5, 2017		100,000		100,000
	$	348,331	$	348,169

On March 23, 2010, the Partnership and its wholly-owned subsidiary, Suburban Energy Finance Corporation, issued $250,000 in aggregate principal amount of 7.375% senior notes due 2020 (the "2020 Senior Notes"). The 2020 Senior Notes were issued at 99.136% of the principal amount. The Partnership's obligations under the 2020 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 2020 Senior Notes are structurally subordinated to, which means they rank effectively behind, any debt and other liabilities of the Operating Partnership. The 2020 Senior Notes mature on March 15, 2020 and require semi-annual interest payments in March and September. The Partnership is permitted to redeem some or all of the 2020 Senior Notes any time at redemption prices specified in the indenture governing the 2020 Senior Notes. In addition, the 2020 Senior Notes 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.

The Operating Partnership has a credit agreement, as amended on January 5, 2012 (the "Amended Credit Agreement") that provides for a five-year $250,000 revolving credit facility (the "Revolving Credit Facility") of which, $100,000 was outstanding as of June 23, 2012 and September 24, 2011. The Amended Credit Agreement amends the previous credit agreement to, among other things, extend the maturity date from June 25, 2013 to January 5, 2017, reduce the borrowing rate and commitment fees, and amend certain affirmative and negative covenants. 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.

At the time the amendment was entered into, the Operating Partnership had existing borrowings of $100,000 under the revolving credit facility of the previous credit agreement, which borrowings have been rolled into the Revolving Credit Facility of the Amended Credit Agreement. In addition, at the time the amendment was entered into, the Operating Partnership had letters of credit issued under the revolving credit facility of the previous credit agreement primarily in support of retention levels under its self-insurance programs, all of which have been rolled into the Revolving Credit Facility of the Amended Credit Agreement. As of June 23, 2012, the Partnership had standby letters of credit issued under the Revolving Credit Facility in the aggregate amount of $46,926 which expire periodically through April 15, 2013. Therefore, as of June 23, 2012 the Partnership had available borrowing capacity of $103,074 under the Revolving Credit Facility.

In connection with the previous revolving credit facility, the Operating Partnership entered into an interest rate swap agreement with a notional amount of $100,000 and an effective date of March 31, 2010 and termination date of June 25, 2013. Under the interest rate swap agreement, the Operating Partnership will pay a fixed interest rate of 3.12% to the issuing lender on the notional principal amount outstanding, effectively fixing the LIBOR portion of the interest rate at 3.12%. In return, the issuing lender will pay to the Operating Partnership a floating rate, namely LIBOR, on the same notional principal amount. The interest rate swap has been designated as a cash flow hedge.

In connection with the Amended Credit Agreement, the Operating Partnership entered into a forward starting interest rate swap agreement with a June 25, 2013 effective date, which is commensurate with the maturity of the existing interest rate swap agreement, and a termination date of January 5, 2017. Under this forward starting interest rate swap agreement, the Operating Partnership will pay a fixed interest rate of 1.63% to the issuing lender on the notional principal amount outstanding, effectively fixing the LIBOR portion of the interest rate at 1.63%. In return, the issuing lender will pay to the Operating Partnership a floating rate, namely LIBOR, on the same notional principal amount. The forward starting interest rate swap has been designated as a cash flow hedge.

Borrowings under the Revolving Credit Facility bear interest at prevailing interest rates based upon, at the Operating Partnership's option, LIBOR plus the applicable margin or the base rate, defined as the higher of the Federal Funds Rate plus  ¹/₂ of 1%, the agent bank's prime rate, or LIBOR plus 1%, plus in each case the applicable margin. The applicable margin is dependent upon the Partnership's ratio of total debt to EBITDA on a consolidated basis, as defined in the Revolving Credit Facility. As of June 23, 2012, the interest rate for the Revolving Credit Facility was approximately 2.7%. The interest rate and the applicable margin will be reset at the end of each calendar quarter.

The Partnership acts as a guarantor 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.

The Amended Credit Agreement and the 2020 Senior Notes both contain various restrictive and affirmative covenants applicable to the Operating Partnership 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. The Amended Credit Agreement contains certain financial covenants (a) requiring the Partnership's consolidated interest coverage ratio, as defined, 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, of the Partnership from being greater than 4.75 to 1.0 as of the end of any fiscal quarter; and (c) prohibiting the Operating Partnership's senior secured consolidated leverage ratio, as defined, from being greater than 3.0 to 1.0 as of the end of any fiscal quarter. Under the indenture governing the 2020 Senior Notes, the Partnership is 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 the Partnership's consolidated fixed charge coverage ratio, as defined, is greater than 1.75 to 1.0. The Partnership and the Operating Partnership were in compliance with all covenants and terms of the 2020 Senior Notes and the Amended Credit Agreement as of June 23, 2012.

On April 25, 2012, the Partnership received consents from the requisite lenders under the Amended Credit Agreement to enable the Partnership to incur additional indebtedness, make amendments to the Amended Credit Agreement to adjust certain covenants, and otherwise perform our obligations as contemplated by the Inergy Propane Acquisition see Note 16. Subsequent Event - Acquisition of Inergy Propane for a description of further amendments to the Amended Credit Agreement and the new senior notes issued by the Partnership in connection with the Inergy Propane Acquisition.

Debt origination costs representing the costs incurred in connection with the placement of, and the subsequent amendment to, long-term borrowings are capitalized within other assets and amortized on a straight-line basis over the term of the respective debt agreements. In connection with the execution of the Amendment Credit Agreement, the Partnership recognized a non-cash charge of $507 to write-off a portion of unamortized debt origination costs associated with the previous credit agreement, and capitalized $2,420 for origination costs incurred with the amendment. During the third quarter of fiscal 2012, the Partnership capitalized $1,772 for origination costs incurred in connection with the issuance of new senior notes in August 2012 in connection with the Inergy Propane Acquisition. Other assets at June 23, 2012 and September 24, 2011 include debt origination costs with a net carrying amount of $9,747 and $7,207, respectively.

The aggregate amounts of long-term debt maturities subsequent to June 23, 2012 are as follows: fiscal 2012 through fiscal 2016: $-0-; and thereafter: $350,000.

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Distributions of Available Cash

9 Months Ended

Jun. 23, 2012

Distributions of Available Cash (Details) [Abstract]

Distributions of Available Cash

8. Distributions of Available Cash

The Partnership makes distributions to its limited partners no later than 45 days after the end of each fiscal quarter of the Partnership 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 18, 2012, the Partnership announced a quarterly distribution of $0.8525 per Common Unit, or $3.41 per Common Unit on an annualized basis, in respect of the third quarter of fiscal 2012, payable on August 7, 2012 to holders of record on July 31, 2012.

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Commitments and Contingencies

9 Months Ended

Jun. 23, 2012

Commitments and Contingencies [Abstract]

Commitments and Contingencies

10. 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 23, 2012 and September 24, 2011, the Partnership had accrued insurance liabilities of $51,664 and $52,841, respectively, representing the total estimated losses under these self-insurance programs. For the portion of the estimated self-insurance liability that exceeds insurance deductibles, the Partnership records an asset within other assets (or other current assets, as applicable) related to the amount of the liability expected to be covered by insurance which amounted to $16,943 and $17,513 as of June 23, 2012 and September 24, 2011, respectively.

Legal Matters. The Partnership's operations are subject to all 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 arising in the ordinary course of business, both as a result of these operating hazards and risks, and as a result of other aspects of its business. In this last regard, the Partnership currently is a defendant in suits in several states, including two putative class actions in which no class has yet been certified. The complaints allege a number of commercial claims, including as to the Partnership's pricing, fee disclosure and tank ownership, under various consumer statutes, the Uniform Commercial Code, common law and antitrust law. Based on the nature of the allegations under these commercial suits, the Partnership believes that the suits are without merit and the Partnership is contesting each of these suits vigorously. With respect to the pending commercial suits, other than for legal defense fees and expenses, based on the merits of the allegations and discovery to date, no liability for a loss contingency is required.

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Financial Instruments and Risk Management (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended			3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended	9 Months Ended
	Jun. 23, 2012	Jun. 25, 2011	Sep. 24, 2011	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member]	Jun. 25, 2011 Derivatives not designated as hedging instruments [Member]	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member]	Jun. 25, 2011 Derivatives not designated as hedging instruments [Member]	Jun. 23, 2012 Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 25, 2011 Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 23, 2012 Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 25, 2011 Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 23, 2012 Interest expense [Member] Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 25, 2011 Interest expense [Member] Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 23, 2012 Interest expense [Member] Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 25, 2011 Interest expense [Member] Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 23, 2012 Commodity options [Member] Cost of products sold [Member] Derivatives not designated as hedging instruments [Member]	Jun. 25, 2011 Commodity options [Member] Cost of products sold [Member] Derivatives not designated as hedging instruments [Member]	Jun. 23, 2012 Commodity options [Member] Cost of products sold [Member] Derivatives not designated as hedging instruments [Member]	Jun. 25, 2011 Commodity options [Member] Cost of products sold [Member] Derivatives not designated as hedging instruments [Member]	Jun. 23, 2012 Commodity futures [Member] Cost of products sold [Member] Derivatives not designated as hedging instruments [Member]	Jun. 25, 2011 Commodity futures [Member] Cost of products sold [Member] Derivatives not designated as hedging instruments [Member]	Jun. 23, 2012 Commodity futures [Member] Cost of products sold [Member] Derivatives not designated as hedging instruments [Member]	Jun. 25, 2011 Commodity futures [Member] Cost of products sold [Member] Derivatives not designated as hedging instruments [Member]	Jun. 23, 2012 Interest rate swaps [Member] Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 23, 2012 Interest rate swaps [Member] Derivatives in Cash Flow Hedging Relationships [Member]	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member]	Sep. 24, 2011 Derivatives not designated as hedging instruments [Member]	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member] Commodity options [Member] Other current assets [Member]	Sep. 24, 2011 Derivatives not designated as hedging instruments [Member] Commodity options [Member] Other current assets [Member]	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member] Commodity options [Member] Other assets [Member]	Sep. 24, 2011 Derivatives not designated as hedging instruments [Member] Commodity options [Member] Other assets [Member]	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member] Commodity options [Member] Other current liabilities [Member]	Sep. 24, 2011 Derivatives not designated as hedging instruments [Member] Commodity options [Member] Other current liabilities [Member]	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member] Commodity options [Member] Other liabilities [Member]	Sep. 24, 2011 Derivatives not designated as hedging instruments [Member] Commodity options [Member] Other liabilities [Member]	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member] Commodity futures [Member]	Sep. 24, 2011 Derivatives not designated as hedging instruments [Member] Commodity futures [Member]	Jun. 23, 2012 Derivatives not designated as hedging instruments [Member] Commodity futures [Member] Other current assets [Member]	Sep. 24, 2011 Derivatives not designated as hedging instruments [Member] Commodity futures [Member] Other current assets [Member]	Jun. 23, 2012 Derivatives designated as hedging instruments [Member]	Sep. 24, 2011 Derivatives designated as hedging instruments [Member]	Jun. 23, 2012 Derivatives designated as hedging instruments [Member] Interest rate swaps [Member] Other current liabilities [Member]	Sep. 24, 2011 Derivatives designated as hedging instruments [Member] Interest rate swaps [Member] Other current liabilities [Member]	Jun. 23, 2012 Derivatives designated as hedging instruments [Member] Interest rate swaps [Member] Other liabilities [Member]	Sep. 24, 2011 Derivatives designated as hedging instruments [Member] Interest rate swaps [Member] Other liabilities [Member]
Financial Instruments and Risk Management [Abstract]
Maximum maturity period of highly liquid investment considered as cash equivalents	3 months
Margin over LIBOR Rate (in hundredths)	1.00%
Derivatives, Fair Value [Line Items]
Fair value - assets																												$ 7,263	$ 3,710	$ 0	$ 612					$ 9,215	$ 5,454	$ 1,952	$ 1,132
Fair value - liabilities																										1,338	2,476					1,338	2,407	0	69					4,822	4,596	2,646	2,662	2,176	1,934
Asset Fair Value Measurement Using Significant Unobservable Inputs (Level 3 ) [Roll Forward]
Opening balance of over-the-counter options	1,780	1,509
Beginning balance realized during the period	(758)	(1,509)
Contracts purchased during the period	3,245	2,778
Change in the fair value of beginning balance	2,678	0
Closing balance of over-the-counter options	6,945	2,778
Liability Fair Value Measurement Using Significant Unobservable Inputs (Level 3 ) [Roll Forward]
Opening balance of over-the-counter options	118	29
Beginning balance realized during the period	(15)	(29)
Contracts purchased during the period	259	226
Change in the fair value of beginning balance	669	0
Closing balance of over-the-counter options	1,031	226
Weighted average maturity of outstanding commodity-related derivatives	3 months		4 months
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Unrealized Gains (Losses) Recognized in Income				8,218	(313)	7,170	2,237									6,465	(516)	6,350	283	1,753	203	820	1,954
Gains (Losses) Recognized in OCI (Effective Portion)								(1,856)	(1,077)	(2,234)	(851)													(1,856)	(2,234)
Gains (Losses) Reclassified from Accumulated OCI into Income (Effective Portion)								(670)	(719)	(2,008)	(2,147)	(670)	(719)	(2,008)	(2,147)
Fair Value of 2020 Senior Notes	$ 262,500		$ 248,500

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Recently Issued Accounting Pronouncements

9 Months Ended

Jun. 23, 2012

Recently Issued Accounting Pronouncements [Abstract]

Recently Issued Accounting Pronouncements

15. Recently Issued Accounting Pronouncements

In June 2011, the FASB issued an accounting standards update to provide guidance on increasing the prominence of items reported in other comprehensive income. This update eliminates the option to present components of other comprehensive income as part of the statement of partners' capital and requires net income and the components of other comprehensive income be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. Early adoption of this updated guidance is permitted, and it becomes effective retrospectively for fiscal years beginning after December 15, 2011, which will be the first quarter of the Partnership's 2013 fiscal year. This update does not change the items that must be reported in other comprehensive income but will require the Partnership to change its historical practice of showing comprehensive income within the Statement of Partners' Capital.

In September 2011, the FASB issued an accounting standards update allowing companies to first assess qualitative factors to determine whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount. If, as a result of the qualitative assessment, it is more likely than not that the fair value of a reporting unit is less than its carrying amount, a more detailed two-step goodwill impairment test would be performed to identify a potential goodwill impairment and measure the amount of loss to be recognized, if any. The standard is effective for annual and interim goodwill impairment tests performed for fiscal years beginning after December 15, 2011, which will be the Partnership's 2013 fiscal year. Early adoption is permitted. The adoption of this standard is not expected to impact the Partnership's financial position, results of operations or cash flows.

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Goodwill (Tables)

9 Months Ended

Jun. 23, 2012

Goodwill [Abstract]

Carrying values of goodwill assigned to the operating segments

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

	As of
	June 23,		September 24,
	2012		2011
Propane	$	265,313	$	265,313
Fuel oil and refined fuels		4,438		4,438
Natural gas and electricity		7,900		7,900
	$	277,651	$	277,651

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Commitments and Contingencies (Details) (USD $) In Thousands, unless otherwise specified	Jun. 23, 2012	Sep. 24, 2011
Commitments and Contingencies [Abstract]
Accrued insurance liabilities	$ 51,664	$ 52,841
Portion of the estimated self-insurance liability that exceeds insurance deductibles	$ 16,943	$ 17,513

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Jun. 23, 2012	Jun. 25, 2011
Cash flows from operating activities:
Net income	$ 63,482	$ 136,658
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization	23,906	26,304
Loss on debt extinguishment	507	0
Other, net	6,424	1,916
Changes in assets and liabilities:
Accounts receivable	4,152	(22,685)
Inventories	13,576	7,331
Other current and noncurrent assets	(1,644)	3,679
Accounts payable	(11,147)	(7,466)
Accrued employment and benefit costs	(10,580)	(7,296)
Customer deposits and advances	(20,842)	(31,411)
Accrued insurance	(1,177)	(3,339)
Other current and noncurrent liabilities	6,593	6,150
Net cash provided by operating activities	73,250	109,841
Cash flows from investing activities:
Capital expenditures	(14,384)	(17,241)
Acquisition of business	0	(3,195)
Proceeds from sale of property, plant and equipment	2,367	5,567
Net cash (used in) investing activities	(12,017)	(14,869)
Cash flows from financing activities:
Repayments of long-term borrowings	(100,000)	0
Proceeds from long-term borrowings	100,000	0
Issuance costs associated with borrowings	(4,192)	0
Partnership distributions	(90,790)	(90,433)
Net cash (used in) financing activities	(94,982)	(90,433)
Net (decrease) increase in cash and cash equivalents	(33,749)	4,539
Cash and cash equivalents at beginning of period	149,553	156,908
Cash and cash equivalents at end of period	$ 115,804	$ 161,447

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Inventories

9 Months Ended

Jun. 23, 2012

Inventories [Abstract]

Inventories

4. 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 23,		September 24,
	2012		2011
Propane, fuel oil and refined fuels and natural gas	$	50,969	$	64,601
Appliances and related parts		1,362		1,306
	$	52,331	$	65,907

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Long Term Borrowings (Tables)

9 Months Ended

Jun. 23, 2012

Long-Term Borrowings [Abstract]

Long-term borrowings

Long-term borrowings consist of the following:

	As of
	June 23,		September 24,
	2012		2011
7.375% senior notes, due March 15, 2020, net of unamortized discount of $1,669 and $1,831, respectively	$	248,331	$	248,169
Revolving credit facility, due January 5, 2017		100,000		100,000
	$	348,331	$	348,169

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Long Term Borrowings (Details) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Jun. 23, 2012	Sep. 24, 2011
Debt Instrument [Line Items]
Long-term borrowings	$ 348,331	$ 348,169
Interest rate swap agreement [Abstract]
Notional amount	100,000
Effective date	Mar. 31, 2010
Termination date	Jun. 25, 2013
Fixed interest rate (in hundredths)	3.12%
Credit Agreement and 2020 Senior Notes covenants [Abstract]
Total consolidated interest coverage ratio, minimum	2.5 to 1.0
Total consolidated leverage ratio, maximum	4.75 to 1.0
Senior secured consolidated leverage ratio, maximum	3.0 to 1.0
Consolidated fixed charge coverage ratio, minimum	1.75 to 1
Debt Origination Costs [Abstract]
Loss on the extinguishment of debt related to write-off in unamortized debt origination costs and unamortized discount	507
Capitalized debt origination costs	9,747	7,207
Long-term debt maturities [Abstract]
Long-term debt maturities, 2012	0
Long-term debt maturities, 2013	0
Long-term debt maturities, 2014	0
Long-term debt maturities, 2015	0
Long-term debt maturities, 2016	0
Long-term debt maturities thereafter	350,000
Acquisition of Inergy Propane LLC [Member]
Debt Origination Costs [Abstract]
Capitalized debt origination costs	1,772
Revolving credit facility [Member]
Debt Instrument [Line Items]
Long-term borrowings	100,000	100,000
Standby letters of credit issued under the Revolving Credit Facility	46,926	100,000
Available borrowing capacity under Revolving Credit Facility	103,074
Interest rate swap agreement [Abstract]
Revolving Credit Facility, interest rate description	Borrowings under the Revolving Credit Facility bear interest at prevailing interest rates based upon, at the Operating Partnership's option, LIBOR plus the applicable margin or the base rate, defined as the higher of the Federal Funds Rate plus .5 of 1%, the agent bank's prime rate, or LIBOR plus 1%, plus in each case the applicable margin. The applicable margin is dependent upon the Partnership's ratio of total debt to EBITDA on a consolidated basis, as defined in the Revolving Credit Facility.
Revolving Credit Facility, approximate interest rate at period end (in hundredths)	2.70%
Senior notes due 2020 [Member]
Debt Instrument [Line Items]
Long-term borrowings	248,331	248,169
Aggregate principal amount	250,000
Stated interest rate (in hundredths)	7.375%
Percentage of principal amount at which debt was issued (in hundredths)	99.136%
Maturity date	Mar. 15, 2020
Percentage of the principal amount repurchase offer under change of control provision (in hundredths)	101.00%
Number of days after the consummation of the change of control that a rating decline may occur to trigger offer to repurchase debt	90 days
Unamortized discount	1,669	1,831
Amended Credit Agreement Due 2017 [Member]
Debt Instrument [Line Items]
Date public offering completed	2012-01-05
Revolving Credit Facility, term	5 years
Revolving Credit Facility, maximum amount	250,000
Standby letters of credit issued under the Revolving Credit Facility	100,000	100,000
Outstanding standby letters of credit, maximum expiration date of outstanding	Jan. 05, 2017
Interest rate swap agreement [Abstract]
Effective date	Jun. 25, 2013
Termination date	Jan. 05, 2017
Fixed interest rate (in hundredths)	1.63%
Debt Origination Costs [Abstract]
Capitalized debt origination costs	$ 2,420

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Segment Information

9 Months Ended

Jun. 23, 2012

Segment Information [Abstract]

Segment Information

14. Segment Information

The Partnership manages and evaluates its operations in five 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 the summary of significant accounting policies Note in the Partnership's Annual Report on Form 10-K for the fiscal year ended September 24, 2011.

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, and activities from the Partnership's HomeTown Hearth & Grill and Suburban Franchising subsidiaries.

The following table presents certain relevant financial information 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 23, 2012			June 25, 2011			June 23, 2012			June 25, 2011
Revenues:
Propane	$	142,681		$	169,258		$	666,796		$	786,968
Fuel oil and refined fuels		17,533			22,528			92,262			124,448
Natural gas and electricity		12,119			16,691			51,878			68,348
All other		7,268			8,086			26,177			29,208
Total revenues	$	179,601		$	216,563		$	837,113		$	1,008,972
Operating income:
Propane	$	25,270		$	20,434		$	139,251		$	193,700
Fuel oil and refined fuels		(1,789	)		(318	)		4,142			14,437
Natural gas and electricity		1,416			1,789			5,759			10,409
All other		(4,029	)		(3,433	)		(10,358	)		(8,947	)
Corporate		(23,612	)		(18,119	)		(55,123	)		(51,672	)
Total operating income		(2,744	)		353			83,671			157,927
Reconciliation to net income:
Loss on debt extinguishment		-			-			507			-
Interest expense, net		6,479			6,867			19,742			20,532
Provision for income taxes		100			273			(60	)		737
Net income	$	(9,323	)	$	(6,787	)	$	63,482		$	136,658
Depreciation and amortization:
Propane	$	5,142		$	5,011		$	14,997		$	15,326
Fuel oil and refined fuels		1,433			1,378			2,595			2,691
Natural gas and electricity		79			225			382			672
All other		19			34			72			192
Corporate		1,799			3,022			5,860			7,423
Total depreciation and amortization	$	8,472		$	9,670		$	23,906		$	26,304

	As of
	June 23, 2012		September 24, 2011
Assets:
Propane	$	685,576	$	706,008
Fuel oil and refined fuels		38,765		44,973
Natural gas and electricity		14,599		18,675
All other		3,693		3,719
Corporate		153,431		183,084
Total assets	$	896,064	$	956,459