AmeriGas Partners (APU) 10-Q 7 Aug 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Jun. 30, 2014	Jul. 31, 2014
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'AMERIGAS PARTNERS LP	'
Entity Central Index Key	'0000932628	'
Document Type	'10-Q	'
Document Period End Date	30-Jun-14	'
Amendment Flag	'false	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q3	'
Current Fiscal Year End Date	'--09-30	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	92,866,796

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2013
In Thousands, unless otherwise specified
Current assets:	'	'	'
Cash and cash equivalents	$14,655	$12,635	$16,533
Accounts receivable (less allowances for doubtful accounts of $22,880, $18,552 and $23,510, respectively)	311,873	290,701	298,558
Accounts receivable - related parties	1,821	1,509	1,234
Inventories	148,881	158,928	142,406
Derivative financial instruments	4,181	18,036	424
Prepaid expenses and other current assets	11,314	18,883	10,045
Total current assets	492,725	500,692	469,200
Property, plant and equipment (less accumulated depreciation and amortization of $1,280,164, $1,231,688 and $1,194,133, respectively)	1,389,832	1,437,514	1,456,055
Goodwill	1,934,581	1,933,929	1,924,820
Intangible assets, net	468,543	496,328	497,648
Other assets	44,251	41,383	40,487
Total assets	4,329,932	4,409,846	4,388,210
Current liabilities:	'	'	'
Current maturities of long-term debt	9,700	12,014	10,006
Bank loans	92,500	116,900	80,000
Accounts payable - trade	138,086	170,705	127,497
Accounts payable - related parties	537	1,071	1,518
Customer deposits and advances	57,426	128,122	80,194
Derivative financial instruments	238	135	13,573
Other current liabilities	162,533	188,027	164,020
Total current liabilities	461,020	616,974	476,808
Long-term debt	2,285,128	2,288,097	2,293,199
Other noncurrent liabilities	85,772	80,638	87,331
Total liabilities	2,831,920	2,985,709	2,857,338
Commitments and contingencies (note 6)	'	'	'
AmeriGas Partners, L.P. partners’ capital:	'	'	'
Common unitholders (units issued - 92,866,796, 92,824,539 and 92,821,523, respectively)	1,434,093	1,354,187	1,490,680
General partner	16,751	15,930	17,310
Accumulated other comprehensive income (loss)	7,604	14,986	-16,959
Total AmeriGas Partners, L.P. partners’ capital	1,458,448	1,385,103	1,491,031
Noncontrolling interest	39,564	39,034	39,841
Total partners’ capital	1,498,012	1,424,137	1,530,872
Total liabilities and partners’ capital	$4,329,932	$4,409,846	$4,388,210

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2013
In Thousands, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]	'	'	'
Allowances for doubtful accounts	$22,880	$18,552	$23,510
Depreciation and amortization on property, plant and equipment	$1,280,164	$1,231,688	$1,194,133
Common units, issued (in units)	92,866,796	92,824,539	92,821,523

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues:	'	'	'	'
Propane	$549,976	$518,361	$2,941,701	$2,413,802
Other	63,261	63,358	210,985	220,771
Total, Revenues	613,237	581,719	3,152,686	2,634,573
Costs and expenses:	'	'	'	'
Cost of sales - propane (excluding depreciation shown below)	320,839	283,037	1,750,500	1,306,728
Cost of sales - other (excluding depreciation shown below)	22,822	22,657	61,336	63,460
Operating and administrative expenses	225,141	224,452	744,007	733,267
Depreciation	37,069	41,738	116,925	117,668
Amortization	10,788	10,775	32,411	32,825
Other income, net	-7,848	-7,579	-21,534	-23,385
Total, costs and expenses	608,811	575,080	2,683,645	2,230,563
Operating income	4,426	6,639	469,041	404,010
Interest expense	-41,328	-41,247	-124,964	-124,219
(Loss) income before income taxes	-36,902	-34,608	344,077	279,791
Income tax (expense) benefit	-847	59	-2,204	-516
Net (loss) income	-37,749	-34,549	341,873	279,275
Less: net income attributable to noncontrolling interest	-12	-46	-4,633	-3,997
Net (loss) income attributable to AmeriGas Partners, L.P.	-37,761	-34,595	337,240	275,278
General partner’s interest in net (loss) income attributable to AmeriGas Partners, L.P.	6,155	5,045	20,689	16,648
Limited partners’ interest in net (loss) income attributable to AmeriGas Partners, L.P.	($43,916)	($39,640)	$316,551	$258,630
(Loss) income per limited partner unit - basic and diluted:	'	'	'	'
Basic (in usd per unit)	($0.47)	($0.43)	$3.04	$2.70
Diluted (in usd per unit)	($0.47)	($0.43)	$3.04	$2.70
Average limited partner units outstanding (thousands):	'	'	'	'
Basic (in shares)	92,888	92,838	92,873	92,830
Diluted (in shares)	92,888	92,838	92,941	92,904

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Net (loss) income	($37,749)	($34,549)	$341,873	$279,275
Other comprehensive income (loss):	'	'	'	'
Net gains (losses) on derivative instruments	884	-19,434	46,231	-24,348
Reclassifications of net (gains) losses on derivative instruments	-5,258	8,479	-53,685	51,229
Other comprehensive (loss) income	-4,374	-10,955	-7,454	26,881
Total comprehensive (loss) income	-42,123	-45,504	334,419	306,156
Add comprehensive loss (deduct comprehensive income) attributable to noncontrolling interest	32	65	-4,561	-4,268
Comprehensive (loss) income attributable to AmeriGas Partners, L.P.	($42,091)	($45,439)	$329,858	$301,888

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Cash Flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'
Net income	$341,873	$279,275
Adjustments to reconcile net income to net cash from operating activities	'	'
Depreciation and amortization	149,336	150,493
Provision for uncollectible accounts	23,254	12,045
Other, net	4,293	3,038
Net change in:	'	'
Accounts receivable	-44,642	-46,531
Inventories	10,111	21,358
Accounts payable	-33,132	-43,423
Other current assets	6,274	9,472
Other current liabilities	-94,176	-113,348
Net cash provided by operating activities	363,191	272,379
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'
Expenditures for property, plant and equipment	-80,291	-80,736
Proceeds from disposals of assets	-12,572	-5,891
Acquisitions of businesses, net of cash acquired	-1,933	-1,045
Net cash used by investing activities	-69,652	-75,890
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'
Distributions	-257,597	-242,795
Noncontrolling interest activity	-4,031	-3,879
(Decrease) increase in bank loans	-24,400	30,100
Repayments of long-term debt	-5,662	-24,806
Proceeds associated with equity-based compensation plans, net of tax withheld	146	1,312
Capital contributions from General Partner	25	10
Net cash used by financing activities	-291,519	-240,058
Cash and cash equivalents increase (decrease)	2,020	-43,569
CASH AND CASH EQUIVALENTS:	'	'
End of period	14,655	16,533
Beginning of period	12,635	60,102
Increase (decrease)	$2,020	($43,569)

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Partner's Capital (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Beginning Balance (in usd)	'	'	$1,424,137	$1,468,560
Net income	-37,749	-34,549	341,873	279,275
Net gains (losses) on derivative instruments	884	-19,434	46,231	-24,348
Reclassifications of net (gains) losses on derivative instruments	-5,258	8,479	-53,685	51,229
Distributions	'	'	-261,628	-246,674
Unit-based compensation expense	'	'	2,002	2,996
Common Units issued in connection with incentive compensation plans, net of tax withheld (in usd)	'	'	-918	-166
Ending Balance (in usd)	1,498,012	1,530,872	1,498,012	1,530,872
Total AmeriGas Partners, L.P. Partners' Capital	'	'	'	'
Beginning Balance (in usd)	'	'	1,385,103	1,429,108
Net income	'	'	337,240	275,278
Net gains (losses) on derivative instruments	'	'	45,761	-24,102
Reclassifications of net (gains) losses on derivative instruments	'	'	-53,143	50,712
Distributions	'	'	-257,597	-242,795
Unit-based compensation expense	'	'	2,002	2,996
Common Units issued in connection with incentive compensation plans, net of tax withheld (in usd)	'	'	-918	-166
Ending Balance (in usd)	1,458,448	1,491,031	1,458,448	1,491,031
Limited Partner	'	'	'	'
Beginning Balance (in units)	'	'	92,824,539	92,801,347
Beginning Balance (in usd)	'	'	1,354,187	1,455,702
Net income	'	'	316,551	258,630
Distributions	'	'	-237,704	-226,472
Unit-based compensation expense	'	'	2,002	2,996
Common Units issued in connection with incentive compensation plans, net of tax withheld (in units)	'	'	42,257	20,176
Common Units issued in connection with incentive compensation plans, net of tax withheld (in usd)	'	'	-943	-176
Ending Balance (in units)	92,866,796	92,821,523	92,866,796	92,821,523
Ending Balance (in usd)	1,434,093	1,490,680	1,434,093	1,490,680
General Partner	'	'	'	'
Beginning Balance (in usd)	'	'	15,930	16,975
Net income	'	'	20,689	16,648
Distributions	'	'	-19,893	-16,323
Common Units issued in connection with incentive compensation plans, net of tax withheld (in usd)	'	'	25	10
Ending Balance (in usd)	16,751	17,310	16,751	17,310
Accumulated Other Comprehensive Income (Loss)	'	'	'	'
Beginning Balance (in usd)	'	'	14,986	-43,569
Net gains (losses) on derivative instruments	'	'	45,761	-24,102
Reclassifications of net (gains) losses on derivative instruments	'	'	-53,143	50,712
Ending Balance (in usd)	7,604	-16,959	7,604	-16,959
Noncontrolling Interest	'	'	'	'
Beginning Balance (in usd)	'	'	39,034	39,452
Net income	'	'	4,633	3,997
Net gains (losses) on derivative instruments	'	'	470	-246
Reclassifications of net (gains) losses on derivative instruments	'	'	-542	517
Distributions	'	'	-4,031	-3,879
Ending Balance (in usd)	$39,564	$39,841	$39,564	$39,841

Nature_of_Operations

Nature of Operations	9 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Nature of Operations	'
	Nature of Operations
	AmeriGas Partners, L.P. (“AmeriGas Partners”) is a publicly traded limited partnership that conducts a national propane distribution business through its principal operating subsidiary AmeriGas Propane, L.P. (“AmeriGas OLP”) and prior to its merger with AmeriGas OLP on July 1, 2013 (the “Merger”), AmeriGas OLP’s principal operating subsidiary Heritage Operating, L.P. (“HOLP”). AmeriGas OLP after the Merger, and AmeriGas OLP and HOLP prior to the Merger, are referred to herein as the “Operating Partnership.” AmeriGas Partners and AmeriGas OLP are Delaware limited partnerships. AmeriGas Partners, the Operating Partnership and its subsidiaries are collectively referred to herein as the “Partnership” or “we.”
	The Operating Partnership is engaged in the distribution of propane and related equipment and supplies. The Operating Partnership comprises the largest retail propane distribution business in the United States serving residential, commercial, industrial, motor fuel and agricultural customers in all 50 states.
	At June 30, 2014, AmeriGas Propane, Inc. (the “General Partner”), an indirect wholly owned subsidiary of UGI Corporation (“UGI”), held a 1% general partner interest in AmeriGas Partners and a 1.01% general partner interest in AmeriGas OLP. The General Partner and its wholly owned subsidiary Petrolane Incorporated (“Petrolane,” a predecessor company of the Partnership) also owned 23,756,882 AmeriGas Partners Common Units (“Common Units”). The remaining Common Units outstanding at June 30, 2014, comprise 69,109,914 publicly held Common Units of which 4,367,362 Common Units are held by a subsidiary of Energy Transfer Partners, L.P. (“ETP”) as a result of the January 12, 2012, acquisition of substantially all of ETP’s propane operations (the “Heritage Acquisition”). The Common Units represent limited partner interests in AmeriGas Partners. AmeriGas Partners holds a 98.99% limited partner interest in AmeriGas OLP. In January 2014 and June 2014, ETP sold 9,200,000 and 8,500,000, respectively, of the Common Units it held in underwritten public offerings, pursuant to its registration rights in its unitholder agreement. AmeriGas Partners did not receive any proceeds from either sale of Common Units by ETP.
	AmeriGas Partners and the Operating Partnership have no employees. Employees of the General Partner conduct, direct and manage our operations. Prior to the Merger, the General Partner provided management and administrative services to Heritage Operating GP, LLC (“HOLP GP”), the general partner of HOLP, under a management services agreement. The General Partner is reimbursed monthly for all direct and indirect expenses it incurs on our behalf (see Note 5).

Significant_Accounting_Policie

Significant Accounting Policies	9 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Significant Accounting Policies	'
	Significant Accounting Policies
	The condensed consolidated financial statements include the accounts of AmeriGas Partners, its majority-owned subsidiary AmeriGas OLP, and its 100%-owned finance subsidiaries AmeriGas Finance Corp., AP Eagle Finance Corp. and AmeriGas Finance, LLC. The accounts of AmeriGas Partners’ majority-owned subsidiary AmeriGas OLP are included based upon the determination that, given the Partnership’s structure, AmeriGas Partners will absorb a majority of AmeriGas OLP’s expected losses, will receive a majority of AmeriGas OLP’s expected residual returns, and is AmeriGas OLP’s primary beneficiary. AmeriGas OLP includes the accounts of its wholly owned subsidiaries. We eliminate all significant intercompany accounts and transactions when we consolidate. We account for the General Partner’s 1.01% interest in AmeriGas OLP as noncontrolling interest in the condensed consolidated financial statements.
	AmeriGas Finance Corp., AP Eagle Finance Corp. and AmeriGas Finance LLC are 100%-owned finance subsidiaries of AmeriGas Partners. Their sole purpose is to serve as issuers or co-obligors for debt securities issued or guaranteed by AmeriGas Partners. The 6.75% and 7.00% Senior Notes were co-issued by AmeriGas Finance Corp. and AmeriGas Finance LLC and are fully and unconditionally guaranteed on a senior unsecured basis by AmeriGas Partners.
	The accompanying condensed consolidated financial statements are unaudited and have been prepared in accordance with the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”). They include all adjustments which we consider necessary for a fair statement of the results for the interim periods presented. Such adjustments consist only of normal recurring items unless otherwise disclosed. The September 30, 2013, condensed consolidated balance sheet data was derived from audited financial statements but does not include all disclosures required by accounting principles generally accepted in the United States of America (“GAAP”).
	These financial statements should be read in conjunction with the financial statements and related notes included in our Annual Report on Form 10-K for the fiscal year ended September 30, 2013 (“the Partnership’s 2013 Annual Financial Statements and Notes”). Weather significantly impacts demand for propane and profitability because many customers use propane for heating purposes. Due to the seasonal nature of the Partnership’s propane business, the results of operations for interim periods are not necessarily indicative of the results to be expected for a full year.
	Allocation of Net Income Attributable to AmeriGas Partners. Net income attributable to AmeriGas Partners, L.P. for partners’ capital and statement of operations presentation purposes is allocated to the General Partner and the limited partners in accordance with their respective ownership percentages after giving effect to amounts distributed to the General Partner in excess of its 1% general partner interest in AmeriGas Partners based on its incentive distribution rights (“IDRs”) under the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, as amended (“Partnership Agreement”).
	Net Income Per Unit. Income per limited partner unit is computed in accordance with GAAP regarding the application of the two-class method for determining income per unit for master limited partnerships (“MLPs”) when IDRs are present. The two-class method requires that income per limited partner unit be calculated as if all earnings for the period were distributed and requires a separate calculation for each quarter and year-to-date period. In periods when our net income attributable to AmeriGas Partners exceeds our Available Cash, as defined in the Partnership Agreement, and is above certain levels, the calculation according to the two-class method results in an increased allocation of undistributed earnings to the General Partner. Generally, in periods when our Available Cash in respect of the quarter or year-to-date periods exceeds our net income (loss) attributable to AmeriGas Partners, the calculation according to the two-class method results in an allocation of earnings to the General Partner greater than its relative ownership interest in the Partnership (or in the case of a net loss attributable to AmeriGas Partners, an allocation of such net loss to the Common Unitholders greater than their relative ownership interest in the Partnership).
	The following table sets forth reconciliations of the numerators and denominators of the basic and diluted income per limited partner unit computations:
		Three Months Ended						Nine Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Net (loss) income attributable to AmeriGas Partners, L.P.	$	(37,761	)	$	(34,595	)	$	337,240		$	275,278
	Adjust for general partner share and theoretical distributions of net income (loss) attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs	(6,155		)	(5,045		)	(54,601		)	(24,195		)
	Common Unitholders’ interest in net (loss) income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs	$	(43,916	)	$	(39,640	)	$	282,639		$	251,083
	Weighted average Common Units outstanding—basic (thousands)	92,888			92,838			92,873			92,830
	Potentially dilutive Common Units (thousands)	—			—			68			74
	Weighted average Common Units outstanding—diluted (thousands)	92,888			92,838			92,941			92,904
	Theoretical distributions of net income attributable to AmeriGas Partners, L.P. in accordance with the two-class method for the nine months ended June 30, 2014 and 2013, resulted in an increased allocation of net income attributable to AmeriGas Partners, L.P. to the General Partner in the computation of income per limited partner unit which had the effect of decreasing earnings per limited partner unit by $0.37 and $0.08, respectively. There was no dilutive effect based on the computation of income (loss) per limited partner unit in accordance with the two-class method for the three months ended June 30, 2014 and 2013.
	Potentially dilutive Common Units included in the diluted limited partner units outstanding computation reflect the effects of restricted Common Unit awards granted under the General Partner’s incentive compensation plans.
	Comprehensive Income. Comprehensive income (loss) comprises net income (loss) and other comprehensive income (loss). Other comprehensive income (loss) principally results from gains and losses on derivative instruments qualifying as cash flow hedges, net of reclassifications to net income. For information regarding the amounts and line items on the Condensed Consolidated Statements of Operations associated with reclassifications from accumulated other comprehensive income (“AOCI”), see Note 8.
	Reclassifications. Certain prior period amounts have been reclassified to conform to current period presentation.
	Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions.

Accounting_Changes

Accounting Changes	9 Months Ended
	Jun. 30, 2014
Accounting Changes and Error Corrections [Abstract]	'
Accounting Changes	'
	Accounting Changes
	Adoption of New Accounting Standards
	Disclosures about Reclassifications Out of Accumulated Other Comprehensive Income. Beginning in Fiscal 2014, the Partnership adopted new accounting guidance regarding disclosures for items reclassified out of AOCI. The disclosures required by the new accounting guidance are included in the notes to the condensed consolidated financial statements. The new disclosures are applied prospectively. As this guidance only affects disclosure requirements, the adoption of this guidance did not impact our results of operations, cash flows or financial position.
	Disclosures about Offsetting Assets and Liabilities. Effective October 1, 2013, the Partnership adopted new accounting guidance requiring entities to disclose both gross and net information about recognized derivative instruments that are offset on the balance sheet as a result of an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset on the balance sheet. The new disclosures are applied retroactively for all periods presented. The required disclosures are included in Note 7 to the condensed consolidated financial statements. As this guidance only affects disclosure requirements, the adoption of this guidance did not impact our results of operations, cash flows or financial position.
	Accounting Standards Not Yet Adopted
	Revenue Recognition. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers.” This ASU supersedes the revenue recognition requirements in Accounting Standards Codification 605, “Revenue Recognition,” and most industry-specific guidance included in the Codification. The standard requires that an entity recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. This standard is effective for the Partnership beginning in fiscal 2018 and allows for either full retrospective adoption or modified retrospective adoption. The Partnership’s management is in the process of assessing the impact of the adoption of ASU 2014-09 on its results of operations, cash flows and financial position.
	Discontinued Operations. In April 2014, the FASB issued authoritative guidance amending existing requirements for reporting discontinued operations.  Under the new guidance, discontinued operations reporting will be limited to disposal transactions that represent strategic shifts having a major effect on operations and financial results. The amended guidance also enhances disclosures and requires assets and liabilities of a discontinued operation to be classified as such for all periods presented in the financial statements. Public entities will apply the amended guidance prospectively to all disposals occurring within annual periods beginning on or after December 15, 2014, and interim periods within those years. The Partnership will adopt this standard on October 1, 2015.  Due to the change in requirements for reporting discontinued operations described above, presentation and disclosure of future disposal transactions after adoption may be different than under current standards.

Goodwill_and_Intangible_Assets

Goodwill and Intangible Assets	9 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill and Intangible Assets	'
	Goodwill and Intangible Assets
	The Partnership’s goodwill and intangible assets comprise the following:
		June 30,			September 30,			June 30,
		2014			2013			2013
	Goodwill (not subject to amortization)	$	1,934,581		$	1,933,929		$	1,924,820
	Intangible assets:
	Customer relationships and noncompete agreements	$	513,716		$	512,665		$	505,580
	Trademarks and tradenames (not subject to amortization)	82,944			82,944			81,800
	Gross carrying amount	596,660			595,609			587,380
	Accumulated amortization	(128,117		)	(99,281		)	(89,732		)
	Intangible assets, net	$	468,543		$	496,328		$	497,648
	We amortize customer relationship and noncompete agreement intangible assets over their estimated periods of benefit which do not exceed 15 years. Amortization expense of intangible assets was $9,596 and $28,836 for the three and nine months ended June 30, 2014, respectively, and $9,585 and $29,261 for the three and nine months ended June 30, 2013, respectively. No amortization is included in cost of sales in the Condensed Consolidated Statements of Operations. As of June 30, 2014, our expected aggregate amortization expense of intangible assets for the remainder of Fiscal 2014 and the next four fiscal years is as follows: remainder of Fiscal 2014 — $9,596; Fiscal 2015 — $37,309; Fiscal 2016 — $36,018; Fiscal 2017 — $33,853; Fiscal 2018 — $32,493.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	Related Party Transactions
	Pursuant to the Partnership Agreement and, prior to the Merger, a management services agreement among HOLP GP, HOLP and the General Partner, the General Partner is entitled to reimbursement for all direct and indirect expenses incurred or payments it makes on our behalf. These costs, which totaled $129,799 and $130,079 for the three months ended June 30, 2014 and 2013, respectively, and $429,750 and $420,581 for nine months ended June 30, 2014 and 2013, respectively, include employee compensation and benefit expenses of employees of the General Partner and general and administrative expenses.
	UGI provides certain financial and administrative services to the General Partner. UGI bills the General Partner monthly for all direct and indirect corporate expenses incurred in connection with providing these services and the General Partner is reimbursed by the Partnership for these expenses. The allocation of indirect UGI corporate expenses to the Partnership utilizes a weighted, three-component formula based on the relative percentage of the Partnership’s revenues, operating expenses and net assets employed to the total of such items for all UGI operating subsidiaries for which general and administrative services are provided. The General Partner believes that this allocation method is reasonable and equitable to the Partnership. Such corporate expenses totaled $4,322 and $4,218, during the three months ended June 30, 2014 and 2013, respectively, and $15,280 and $14,974 during the nine months ended June 30, 2014 and 2013, respectively. In addition, UGI and certain of its subsidiaries provide office space, stop loss medical coverage and automobile liability insurance to the Partnership. The costs related to these items totaled $976 and $872 for the three months ended June 30, 2014 and 2013, respectively, and $3,191 and $3,498 for the nine months ended June 30, 2014 and 2013, respectively.
	From time to time, AmeriGas OLP purchases propane on an as needed basis from UGI Energy Services, LLC. (“Energy Services”). In addition, the Partnership sells propane to Energy Services and certain other affiliates of UGI. Such amounts were not material during the periods presented.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	Commitments and Contingencies
	Federal Trade Commission Investigation of Propane Grill Cylinder Filling Practices. On or about November 4, 2011, the General Partner received notice that the Federal Trade Commission (“FTC”) had initiated an antitrust and consumer protection investigation into certain practices of the Partnership relating to the filling of portable propane cylinders. On February 2, 2012, the Partnership received a Civil Investigative Demand from the FTC that requested documents and information concerning, among other things, (i) the Partnership’s decision, in 2008, to reduce the volume of propane in cylinders it sells to consumers from 17 pounds to 15 pounds, and (ii) cross-filling, related service arrangements and communications regarding the foregoing with competitors. The Partnership responded to that subpoena and cooperated with subsequent requests for information. On March 27, 2014, the FTC issued an administrative complaint against the Partnership and UGI alleging that the General Partner and one of its competitors colluded in 2008 to persuade its common customer, Walmart Stores, Inc., to accept the cylinder fill reduction from 17 pounds to 15 pounds.  The complaint does not seek monetary remedies.  The Partnership and UGI filed their Answer to the complaint on April 18, 2014, and believe that they have good defenses to the FTC’s claims.  We are unable to reasonably estimate the impact, if any, arising from this claim.
	Purported Class Action Lawsuits.  Following the issuance of the FTC’s administrative complaint described above, more than 25 class action lawsuits have been filed in multiple jurisdictions against the Partnership/UGI Corporation and a competitor by certain of their direct and indirect customers.  The class action lawsuits allege that the Partnership and its competitor colluded in 2008 to reduce the fill level and combined to persuade its common customer, Walmart Stores, Inc., to accept that fill reduction, resulting in increased cylinder costs to retailers and end-user customers in violation of federal and certain state antitrust laws.  The claims seek treble  damages,  injunctive  relief, attorneys’ fees and costs on behalf of the putative classes.  We believe these lawsuits will eventually be consolidated by a multidistrict litigation panel.  We are unable to reasonably estimate the impact, if any, arising from such litigation.  We believe we have strong defenses to the claims and intend to vigorously defend against them.
	In addition to the matters described above, there are other pending claims and legal actions arising in the normal course of our businesses. Although we cannot predict the final results of these pending claims and legal actions, we believe, after consultation with counsel, that the final outcome of these matters will not have a material effect on our consolidated financial position, results of operations or cash flows.

Fair_Value_Measurement

Fair Value Measurement	9 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	Fair Value Measurements
	Derivative Financial Instruments
	The following table presents our financial assets and financial liabilities that are measured at fair value on a recurring basis for each of the fair value hierarchy levels, including both current and noncurrent portions, as of June 30, 2014, September 30, 2013 and June 30, 2013:
			Asset (Liability)
			Quoted Prices				Significant				Unobservable		Total
			in Active				Other				Inputs
			Markets for				Observable				(Level 3)
			Identical				Inputs
			Assets and				(Level 2)
			Liabilities
			(Level 1)
	June 30, 2014:
	Assets:
	Derivative financial instruments:
	Commodity contracts		$	—			$	4,862			$	—	$	4,862
	Liabilities:
	Derivative financial instruments:
	Commodity contracts		$	—			$	(238	)		$	—	$	(238	)
	September 30, 2013:
	Assets:
	Derivative financial instruments:
	Commodity contracts		$	—			$	18,252			$	—	$	18,252
	Liabilities:
	Derivative financial instruments:
	Commodity contracts		$	—			$	(135	)		$	—	$	(135	)
	June 30, 2013:
	Assets:
	Derivative financial instruments:
	Commodity contracts		$	—			$	424			$	—	$	424
	Liabilities:
	Derivative financial instruments:
	Commodity contracts		$	—			$	(15,224	)		$	—	$	(15,224	)
	The fair values of our non-exchange-traded commodity derivative contracts included in Level 2 are based upon indicative price quotations available through brokers, industry price publications or recent market transactions and related market indicators. For commodity option contracts not traded on an exchange, we use a Black Scholes option pricing model that considers time value and volatility of the underlying commodity.
	Other Financial Instruments
	The carrying amounts of other financial instruments included in current assets and current liabilities (except for current maturities of long-term debt) approximate their fair values because of their short-term nature. At June 30, 2014, the carrying amount and estimated fair value of our long-term debt (including current maturities) were $2,294,828 and $2,495,680, respectively. At June 30, 2013, the carrying amount and estimated fair value of our long-term debt (including current maturities) were $2,303,205 and $2,366,116, respectively. We estimate the fair value of long-term debt by using current market prices and by discounting future cash flows using rates available for similar type debt (Level 2).
	We have financial instruments such as short-term investments and trade accounts receivable which could expose us to concentrations of credit risk. We limit our credit risk from short-term investments by investing only in investment-grade commercial paper and U.S. Government securities. The credit risk from trade accounts receivable is limited because we have a large customer base which extends across many different U.S. markets.
	Disclosures about Offsetting Derivative Assets and Liabilities
	Derivative assets and liabilities are presented net by counterparty on our Condensed Consolidated Balance Sheets if the right of offset exists. Our derivative financial instruments principally comprise propane over-the-counter swap and option contracts. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Certain over-the-counter contracts contain contractual rights of offset through master netting arrangements and contract default provisions. In addition, contracts may be subject to conditional rights of offset through counterparty nonperformance, insolvency, or other conditions.
	In general, most of our over-the-counter transactions are subject to collateral requirements. Cash collateral paid by us to our derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on our Condensed Consolidated Balance Sheets with our derivative counterparties are not included in the tables below but would reduce our net exposure to such counterparties because they are subject to master netting or similar arrangements.
		Gross Amounts Recognized			Gross Amounts Offset in the Balance Sheet			Net Amounts Presented in the Balance Sheet
	June 30, 2014:
	Derivative assets	$	8,068		$	(3,206	)	$	4,862
	Derivative liabilities	$	(3,444	)	$	3,206		$	(238	)
	September 30, 2013:
	Derivative assets	$	19,621		$	(1,369	)	$	18,252
	Derivative liabilities	$	(1,504	)	$	1,369		$	(135	)
	June 30, 2013:
	Derivative assets	$	424		$	—		$	424
	Derivative liabilities	$	(15,224	)	$	—		$	(15,224	)

Disclosures_about_Derivative_I

Disclosures about Derivative Instruments and Hedging Activities	9 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Disclosures About Derivative Instruments and Hedging Activities	'
	Disclosures about Derivative Instruments and Hedging Activities
	The Partnership is exposed to certain market risks related to its ongoing business operations. Management uses derivative financial and commodity instruments, among other things, to manage these risks. The primary risk currently managed by derivative instruments is commodity price risk for propane. Although we use derivative financial and commodity instruments to reduce market risk associated with forecasted transactions, we do not use derivative financial and commodity instruments for speculative or trading purposes. The use of derivative instruments is controlled by our risk management and credit policies which govern, among other things, the derivative instruments the Partnership can use, counterparty credit limits and contract authorization limits.
	Commodity Price Risk
	In order to manage market risk associated with the Partnership’s fixed-price programs, which permit customers to lock in the prices they pay for propane principally during the months of October through March, the Partnership uses over-the-counter derivative commodity instruments, principally price swap and option contracts. In addition, the Partnership from time to time enters into price swap and option agreements to reduce short-term commodity price volatility. At June 30, 2014 and 2013, total volumes associated with LPG commodity derivative instruments totaled 210.3 million gallons and 177.8 million gallons, respectively. At June 30, 2014, for those LPG commodity derivative instruments accounted for as cash flow hedges, the maximum period over which we are hedging propane market price risk is 24 months with a weighted average of 7 months.
	During the periods presented in the financial statements, we accounted for a significant portion of our commodity price risk contracts as cash flow hedges. Effective April 1, 2014, the Partnership determined that on a prospective basis it would not elect cash flow hedge accounting for its commodity derivative transactions. All unrealized and realized gains and losses on the Partnership’s derivative commodity transactions entered into beginning April 1, 2014, are included as a component of cost of sales on the Condensed Consolidated Statements of Operations. Changes in the fair values of contracts qualifying for cash flow hedge accounting are recorded in AOCI and noncontrolling interest, to the extent effective in offsetting changes in the underlying commodity price risk, until earnings are affected by the hedged item. At June 30, 2014, the amount of net gains associated with commodity price risk hedges expected to be reclassified into earnings during the next twelve months based upon current fair values is $4,772.
	Derivative Financial Instruments Credit Risk
	The Partnership is exposed to credit loss in the event of nonperformance by counterparties to derivative financial and commodity instruments. Our counterparties principally consist of major energy companies and major U.S. financial institutions. We maintain credit policies with regard to our counterparties that we believe reduce overall credit risk. These policies include evaluating and monitoring our counterparties’ financial condition, including their credit ratings, and entering into agreements with counterparties that govern credit limits. Certain of these agreements call for the posting of collateral by the counterparty or by the Partnership in the forms of letters of credit, parental guarantees or cash. We have concentrations of credit risk associated with derivative financial instruments held by certain derivative financial instrument counterparties. Although we have concentrations of credit risk, the maximum amount of loss due to credit risk that we would incur if these counterparties comprising the concentration failed to perform according to the terms of their contracts was not material at June 30, 2014, based upon the fair values of such derivative instruments. Certain of our derivative contracts have credit-risk-related contingent features that may require the posting of additional collateral in the event of a downgrade in the Partnership’s debt rating. At June 30, 2014, if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material.
	The following table provides information regarding the fair values and balance sheet locations of our derivative assets and liabilities existing as of June 30, 2014 and 2013:
		Derivative Assets										Derivative (Liabilities)
		Balance Sheet		Fair Value								Balance Sheet	Fair Value
		Location		2014				2013				Location	2014			2013
	Derivatives Designated as Hedging Instruments:
	Propane contracts	Derivative financial instruments and other assets		$	6,378			$	424			Derivative financial instruments and other noncurrent liabilities	$	—		$	(15,224	)
	Derivatives Not Designated as Hedging Instruments:
	Propane contracts	Derivative financial instruments		313				—				Derivative financial instruments	(2,067		)	—
	Amounts above offset in the Balance Sheet			(1,829		)		—					1,829			—
	Total Derivatives			$	4,862			$	424				$	(238	)	$	(15,224	)
	The following table provides information on the effects of derivative instruments on the Condensed Consolidated Statements of Operations and changes in AOCI and noncontrolling interest for the three and nine months ended June 30, 2014 and 2013:
	Three Months Ended June 30,
		Gain (Loss) Recognized in								Gain (Loss) Reclassified  from						Location of Gain  (Loss)
		AOCI  and Noncontrolling								AOCI and Noncontrolling						Reclassified from
		Interest								Interest into Income						AOCI and Noncontrolling
		2014				2013				2014			2013			Interest into Income
	Cash Flow Hedges:
	Propane contracts	$	884			$	(19,434	)		$	5,258		$	(8,479	)	Cost of sales - propane
		(Loss)														Location of (Loss)
		Recognized in Income														Recognized in Income
	Derivatives Not Designated as Hedging Instruments:	2014				2013
	Propane contracts	$	(2,006	)		$	—									Cost of sales - propane
	Nine Months Ended June 30,
		Gain (Loss) Recognized in								Gain (Loss) Reclassified  from						Location of Gain  (Loss)
		AOCI  and Noncontrolling								AOCI and Noncontrolling						Reclassified from
		Interest								Interest into Income						AOCI and Noncontrolling
		2014				2013				2014			2013			Interest into Income
	Cash Flow Hedges:
	Propane contracts	$	46,231			$	(24,348	)		$	53,685		$	(51,229	)	Cost of sales - propane
		Gain														Location of Gain
		Recognized in Income														Recognized in Income
	Derivatives Not Designated as Hedging Instruments:	2014				2013
	Propane contracts	$	4,924			$	—									Cost of sales - propane
	The amounts of derivative gains or losses representing ineffectiveness were not material for the three and nine months ended June 30, 2014 and 2013.
	We are also a party to a number of contracts that have elements of a derivative instrument. These contracts include, among others, binding purchase orders and contracts which provide for the purchase and delivery of propane and service contracts that require the counterparty to provide commodity storage or transportation service to meet our normal sales commitments. Although many of these contracts have the requisite elements of a derivative instrument, these contracts qualify for normal purchase and normal sales exception accounting under GAAP because they provide for the delivery of products or services in quantities that are expected to be used in the normal course of operating our business and the price in the contract is based on an underlying that is directly associated with the price of the product or service being purchased or sold.

Error_in_Accounting_for_Certai

Error in Accounting for Certain Customer Credits	9 Months Ended
	Jun. 30, 2014
Accounting Changes and Error Corrections [Abstract]	'
Accounting Changes and Error Corrections	'
	Error in Accounting for Certain Customer Credits
	During the three months ended March 31, 2013, the Partnership identified an error in its accounting for certain customer credits. The Partnership determined that the recording of propane revenues did not appropriately consider the effects of certain customer credits which were recorded when issued in a subsequent period. As a result, the Partnership changed its accounting for customer credits to record an estimate of such credits at the time propane revenues are recorded. Such estimate considers the Partnership’s history of providing credits, propane revenue activity and other factors. During the three months ended March 31, 2013, the Partnership evaluated the impact of the error on prior periods and determined that the effect was not material to the financial statements for the three or six months ended March 31, 2013, or any prior period financial statement and recorded the cumulative effect of the error in accounting for customer credits as of January 1, 2013. If the Partnership had corrected the error in accounting for customer credits for periods prior to Fiscal 2013, net income attributable to AmeriGas Partners, L.P. for the nine months ended June 30, 2013, would have increased by approximately $4,200.

Debt

Debt	9 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt Disclosure	'
	Debt
	In June 2014, AmeriGas OLP entered into an Amended and Restated Credit Agreement (“Amended and Restated Credit Agreement”) with a group of banks which provides for borrowings up to $525 (including a sublimit of $125 for letters of credit). The Amended and Restated Credit Agreement amends and restates AmeriGas OLP’s prior Credit Agreement entered into with a group of banks in June 2011, as amended from time to time. The Amended and Restated Credit Agreement permits AmeriGas OLP to borrow at prevailing interest rates, including the base rate, defined as the higher of the Federal Funds rate plus 0.50% or the agent bank’s prime rate, or at a one-week, one-, two-, three-, or six-month Eurodollar Rate, as defined in the Amended and Restated Credit Agreement, plus a margin. The Amended and Restated Credit Agreement reduces the applicable margin on base rate borrowings to a range of 0.5% to 1.5% (from a range of 0.75% to 1.75% previously); reduces the applicable margin on Eurodollar Rate borrowings to a range of 1.5% to 2.5% (from a range of 1.75% to 2.75% previously); and reduces the facility fee to a range of 0.3% to 0.45% (from a range of 0.3% to 0.5% previously). The aforementioned margins and facility fees are dependent upon AmeriGas Partners’ ratio of debt to earnings before interest expense, income taxes, depreciation and amortization (each as defined in the Amended and Restated Credit Agreement). The Amended and Restated Credit Agreement expires on June 18, 2019.
	The Amended and Restated Credit Agreement restricts the incurrence of additional indebtedness and also restricts certain liens, guarantees, investments, loans and advances, payments, mergers, consolidations, asset transfers, transactions with affiliates, sales of assets, acquisitions and other transactions. The Credit Agreement requires that AmeriGas OLP and AmeriGas Partners maintain ratios of total indebtedness to EBITDA, as defined, below certain thresholds. In addition, the Partnership must maintain a minimum ratio of EBITDA to interest expense, as defined and as calculated on a rolling four-quarter basis. Generally, as long as no default exists or would result therefrom, AmeriGas OLP is permitted to make cash distributions not more frequently than quarterly in an amount not to exceed available cash, as defined, for the immediately preceding calendar quarter.

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	9 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Allocation of Net Income Attributable to AmeriGas Partners	'
	Allocation of Net Income Attributable to AmeriGas Partners. Net income attributable to AmeriGas Partners, L.P. for partners’ capital and statement of operations presentation purposes is allocated to the General Partner and the limited partners in accordance with their respective ownership percentages after giving effect to amounts distributed to the General Partner in excess of its 1% general partner interest in AmeriGas Partners based on its incentive distribution rights (“IDRs”) under the Fourth Amended and Restated Agreement of Limited Partnership of AmeriGas Partners, as amended (“Partnership Agreement”).
Net Income Per Unit	'
	Net Income Per Unit. Income per limited partner unit is computed in accordance with GAAP regarding the application of the two-class method for determining income per unit for master limited partnerships (“MLPs”) when IDRs are present. The two-class method requires that income per limited partner unit be calculated as if all earnings for the period were distributed and requires a separate calculation for each quarter and year-to-date period. In periods when our net income attributable to AmeriGas Partners exceeds our Available Cash, as defined in the Partnership Agreement, and is above certain levels, the calculation according to the two-class method results in an increased allocation of undistributed earnings to the General Partner. Generally, in periods when our Available Cash in respect of the quarter or year-to-date periods exceeds our net income (loss) attributable to AmeriGas Partners, the calculation according to the two-class method results in an allocation of earnings to the General Partner greater than its relative ownership interest in the Partnership (or in the case of a net loss attributable to AmeriGas Partners, an allocation of such net loss to the Common Unitholders greater than their relative ownership interest in the Partnership).
	The following table sets forth reconciliations of the numerators and denominators of the basic and diluted income per limited partner unit computations:
		Three Months Ended						Nine Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Net (loss) income attributable to AmeriGas Partners, L.P.	$	(37,761	)	$	(34,595	)	$	337,240		$	275,278
	Adjust for general partner share and theoretical distributions of net income (loss) attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs	(6,155		)	(5,045		)	(54,601		)	(24,195		)
	Common Unitholders’ interest in net (loss) income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs	$	(43,916	)	$	(39,640	)	$	282,639		$	251,083
	Weighted average Common Units outstanding—basic (thousands)	92,888			92,838			92,873			92,830
	Potentially dilutive Common Units (thousands)	—			—			68			74
	Weighted average Common Units outstanding—diluted (thousands)	92,888			92,838			92,941			92,904
	Theoretical distributions of net income attributable to AmeriGas Partners, L.P. in accordance with the two-class method for the nine months ended June 30, 2014 and 2013, resulted in an increased allocation of net income attributable to AmeriGas Partners, L.P. to the General Partner in the computation of income per limited partner unit which had the effect of decreasing earnings per limited partner unit by $0.37 and $0.08, respectively. There was no dilutive effect based on the computation of income (loss) per limited partner unit in accordance with the two-class method for the three months ended June 30, 2014 and 2013.
	Potentially dilutive Common Units included in the diluted limited partner units outstanding computation reflect the effects of restricted Common Unit awards granted under the General Partner’s incentive compensation plans.
Use of Estimates	'
	Use of Estimates. The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and costs. These estimates are based on management’s knowledge of current events, historical experience and various other assumptions that are believed to be reasonable under the circumstances. Accordingly, actual results may be different from these estimates and assumptions.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	9 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Income per limited partner unit	'
	The following table sets forth reconciliations of the numerators and denominators of the basic and diluted income per limited partner unit computations:
		Three Months Ended						Nine Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
	Net (loss) income attributable to AmeriGas Partners, L.P.	$	(37,761	)	$	(34,595	)	$	337,240		$	275,278
	Adjust for general partner share and theoretical distributions of net income (loss) attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs	(6,155		)	(5,045		)	(54,601		)	(24,195		)
	Common Unitholders’ interest in net (loss) income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs	$	(43,916	)	$	(39,640	)	$	282,639		$	251,083
	Weighted average Common Units outstanding—basic (thousands)	92,888			92,838			92,873			92,830
	Potentially dilutive Common Units (thousands)	—			—			68			74
	Weighted average Common Units outstanding—diluted (thousands)	92,888			92,838			92,941			92,904

Goodwill_and_Intangible_Assets1

Goodwill and Intangible Assets (Tables)	9 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Components of Intangible Assets	'
	The Partnership’s goodwill and intangible assets comprise the following:
		June 30,			September 30,			June 30,
		2014			2013			2013
	Goodwill (not subject to amortization)	$	1,934,581		$	1,933,929		$	1,924,820
	Intangible assets:
	Customer relationships and noncompete agreements	$	513,716		$	512,665		$	505,580
	Trademarks and tradenames (not subject to amortization)	82,944			82,944			81,800
	Gross carrying amount	596,660			595,609			587,380
	Accumulated amortization	(128,117		)	(99,281		)	(89,732		)
	Intangible assets, net	$	468,543		$	496,328		$	497,648

Fair_Value_Measurement_Tables

Fair Value Measurement (Tables)	9 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Financial assets and financial liabilities at fair value on a recurring basis	'
	The following table presents our financial assets and financial liabilities that are measured at fair value on a recurring basis for each of the fair value hierarchy levels, including both current and noncurrent portions, as of June 30, 2014, September 30, 2013 and June 30, 2013:
			Asset (Liability)
			Quoted Prices				Significant				Unobservable		Total
			in Active				Other				Inputs
			Markets for				Observable				(Level 3)
			Identical				Inputs
			Assets and				(Level 2)
			Liabilities
			(Level 1)
	June 30, 2014:
	Assets:
	Derivative financial instruments:
	Commodity contracts		$	—			$	4,862			$	—	$	4,862
	Liabilities:
	Derivative financial instruments:
	Commodity contracts		$	—			$	(238	)		$	—	$	(238	)
	September 30, 2013:
	Assets:
	Derivative financial instruments:
	Commodity contracts		$	—			$	18,252			$	—	$	18,252
	Liabilities:
	Derivative financial instruments:
	Commodity contracts		$	—			$	(135	)		$	—	$	(135	)
	June 30, 2013:
	Assets:
	Derivative financial instruments:
	Commodity contracts		$	—			$	424			$	—	$	424
	Liabilities:
	Derivative financial instruments:
	Commodity contracts		$	—			$	(15,224	)		$	—	$	(15,224	)
Fair Value, by Balance Sheet Grouping	'
	In general, most of our over-the-counter transactions are subject to collateral requirements. Cash collateral paid by us to our derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our counterparties, if any, is reflected in the table below to offset derivative assets. Certain other accounts receivable and accounts payable balances recognized on our Condensed Consolidated Balance Sheets with our derivative counterparties are not included in the tables below but would reduce our net exposure to such counterparties because they are subject to master netting or similar arrangements.
		Gross Amounts Recognized			Gross Amounts Offset in the Balance Sheet			Net Amounts Presented in the Balance Sheet
	June 30, 2014:
	Derivative assets	$	8,068		$	(3,206	)	$	4,862
	Derivative liabilities	$	(3,444	)	$	3,206		$	(238	)
	September 30, 2013:
	Derivative assets	$	19,621		$	(1,369	)	$	18,252
	Derivative liabilities	$	(1,504	)	$	1,369		$	(135	)
	June 30, 2013:
	Derivative assets	$	424		$	—		$	424
	Derivative liabilities	$	(15,224	)	$	—		$	(15,224	)

Recovered_Sheet1

Disclosures About Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Components of Fair Value of Derivative Assets and Liabilities	'
	The following table provides information regarding the fair values and balance sheet locations of our derivative assets and liabilities existing as of June 30, 2014 and 2013:
		Derivative Assets										Derivative (Liabilities)
		Balance Sheet		Fair Value								Balance Sheet	Fair Value
		Location		2014				2013				Location	2014			2013
	Derivatives Designated as Hedging Instruments:
	Propane contracts	Derivative financial instruments and other assets		$	6,378			$	424			Derivative financial instruments and other noncurrent liabilities	$	—		$	(15,224	)
	Derivatives Not Designated as Hedging Instruments:
	Propane contracts	Derivative financial instruments		313				—				Derivative financial instruments	(2,067		)	—
	Amounts above offset in the Balance Sheet			(1,829		)		—					1,829			—
	Total Derivatives			$	4,862			$	424				$	(238	)	$	(15,224	)
Components of Derivative Instruments Gain Loss In Statement of Operations	'
	The following table provides information on the effects of derivative instruments on the Condensed Consolidated Statements of Operations and changes in AOCI and noncontrolling interest for the three and nine months ended June 30, 2014 and 2013:
	Three Months Ended June 30,
		Gain (Loss) Recognized in								Gain (Loss) Reclassified  from						Location of Gain  (Loss)
		AOCI  and Noncontrolling								AOCI and Noncontrolling						Reclassified from
		Interest								Interest into Income						AOCI and Noncontrolling
		2014				2013				2014			2013			Interest into Income
	Cash Flow Hedges:
	Propane contracts	$	884			$	(19,434	)		$	5,258		$	(8,479	)	Cost of sales - propane
		(Loss)														Location of (Loss)
		Recognized in Income														Recognized in Income
	Derivatives Not Designated as Hedging Instruments:	2014				2013
	Propane contracts	$	(2,006	)		$	—									Cost of sales - propane
	Nine Months Ended June 30,
		Gain (Loss) Recognized in								Gain (Loss) Reclassified  from						Location of Gain  (Loss)
		AOCI  and Noncontrolling								AOCI and Noncontrolling						Reclassified from
		Interest								Interest into Income						AOCI and Noncontrolling
		2014				2013				2014			2013			Interest into Income
	Cash Flow Hedges:
	Propane contracts	$	46,231			$	(24,348	)		$	53,685		$	(51,229	)	Cost of sales - propane
		Gain														Location of Gain
		Recognized in Income														Recognized in Income
	Derivatives Not Designated as Hedging Instruments:	2014				2013
	Propane contracts	$	4,924			$	—									Cost of sales - propane

Nature_of_Operations_Narrative

Nature of Operations - Narrative (Details)	1 Months Ended		9 Months Ended
	Jun. 30, 2014	Jan. 31, 2014	Jun. 30, 2014
	Employee		States
			Employee
General Partners Interest	'	'	'
Number of states in which the company has market share (in states)	'	'	50
Common units held by the general partner and its wholly owned subsidiary Petrolane Incorporated	23,756,882	'	23,756,882
Common Units held by public	69,109,914	'	69,109,914
Common Units held by ETP	4,367,362	'	4,367,362
Limited partner interest held by AmeriGas Partners in AmeriGas OLP (as a percent)	'	'	98.99%
Units Issued in Secondary Offering	8,500,000	9,200,000	'
Employees of the AmeriGas Partners and the Operating Partnerships (in employees)	0	'	0
AmeriGas Propane Inc Partnership Interest In AmeriGas Partners	'	'	'
General Partners Interest	'	'	'
General Partners Ownership Interest (as a percent)	1.00%	'	1.00%
AmeriGas Propane Inc Partnership Interest In AmeriGas OLP	'	'	'
General Partners Interest	'	'	'
General Partners Ownership Interest (as a percent)	1.01%	'	1.01%

Significant_Accounting_Policie3

Significant Accounting Policies - Narrative (Details) (USD $)	3 Months Ended	9 Months Ended
	Jun. 30, 2013	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
			AmeriGas Propane Inc Partnership Interest in AmeriGas OLP	AmeriGas Propane Inc Partnership Interest In AmeriGas Partners	AmeriGas Finance Corp., AP Eagle Finance Corp. and AmeriGas Finance LLC	Amerigas Partners Senior Notes Due 2020	Amerigas Partners Senior Notes Due 2022
General Partner Interest	'	'	'	'	'	'	'
General Partners Ownership Interest (as a percent)	'	'	1.01%	1.00%	'	'	'
Ownership Percentage of Finance Subsidiaries	'	'	'	'	100.00%	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	'	'	'	'	6.75%	7.00%
General Partner Interest Percentage	'	'	'	1.00%	'	'	'
Theoretical distributions of net income on earnings (in dollars per unit)	$0.37	$0.08	'	'	'	'	'

Significant_Accounting_Policie4

Significant Accounting Policies - Schedule of Income Per Limited Partner Unit (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Accounting Policies [Abstract]	'	'	'	'
Net income (loss) attributable to AmeriGas Partners, L.P.	($37,761)	($34,595)	$337,240	$275,278
Adjust for general partner share and theoretical distributions of net income (loss) attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs	-6,155	-5,045	-54,601	-24,195
Common Unitholders’ interest in net income (loss) attributable to AmeriGas Partners, L.P. under the two-class method for MLPs	($43,916)	($39,640)	$282,639	$251,083
Weighted average Common Units outstanding—basic (thousands) (in shares)	92,888	92,838	92,873	92,830
Potentially dilutive Common Units (thousands) (in shares)	0	0	68	74
Weighted average Common Units outstanding—diluted (thousands) (in shares)	92,888	92,838	92,941	92,904

Goodwill_and_Intangible_Assets2

Goodwill and Intangible Assets - Narrative (Details) (USD $)	3 Months Ended		9 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Finite-Lived Intangible Assets	'	'	'	'
Finite-Lived Intangible Asset, Useful Life	'15 years	'	'	'
Amortization of Intangible Assets	$9,596,000	$9,585,000	$28,836,000	$29,261,000
Remainder of Fiscal 2014	9,596,000	'	9,596,000	'
Fiscal 2015	37,309,000	'	37,309,000	'
Fiscal 2016	36,018,000	'	36,018,000	'
Fiscal 2017	33,853,000	'	33,853,000	'
Fiscal 2018	32,493,000	'	32,493,000	'
Cost of Sales	'	'	'	'
Finite-Lived Intangible Assets	'	'	'	'
Amortization of Intangible Assets	$0	'	'	'

Recovered_Sheet2

Goodwill And Intangible Assets - Components of Intangible Assets (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2013
In Thousands, unless otherwise specified
Finite-Lived Intangible Assets And Indefinite-Lived Intangible Assets	'	'	'
Goodwill (not subject to amortization)	$1,934,581	$1,933,929	$1,924,820
Customer relationships and noncompete agreements	513,716	512,665	505,580
Trademarks and tradenames (not subject to amortization)	82,944	82,944	81,800
Gross carrying amount	596,660	595,609	587,380
Accumulated amortization	-128,117	-99,281	-89,732
Intangible assets, net	$468,543	$496,328	$497,648

Related_Party_Transactions_Nar

Related Party Transactions - Narrative (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
General Partner Expense	'	'	'	'
Related Party Transaction	'	'	'	'
Costs and Expenses, Related Party	$129,799	$130,079	$429,750	$420,581
UGI Corp Expense Reimbursement	'	'	'	'
Related Party Transaction	'	'	'	'
Costs and Expenses, Related Party	4,322	4,218	15,280	14,974
UGI Corp Office Insurance Reimbursement	'	'	'	'
Related Party Transaction	'	'	'	'
Costs and Expenses, Related Party	$976	$872	$3,191	$3,498

Commitments_and_Contingencies_

Commitments and Contingencies - Narrative (Details)	9 Months Ended
	Jun. 30, 2014
	lb
FTC Investigation	'
Loss Contingencies	'
Amount of propane in cylinders before reduction (in pounds)	17
Amount of propane in cylinders after reduction (in pounds)	15
Minimum	'
Loss Contingencies	'
Class action lawsuits (more than 20)	20

Fair_Value_Measurement_Fair_Va

Fair Value Measurement Fair Value Measurements - Narrative (Details) (USD $)	Jun. 30, 2014	Jun. 30, 2013
In Thousands, unless otherwise specified
Fair Value Disclosures [Abstract]	'	'
Long-term Debt, Carrying Value	$2,294,828	$2,303,205
Long-term Debt, Fair Value	$2,495,680	$2,366,116

Fair_Value_Measurement_Financi

Fair Value Measurement - Financial Assets and Financial Liabilities at Fair Value On a Recurring Basis (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2013
In Thousands, unless otherwise specified
Assets:	'	'	'
Derivative Assets	$4,862	$18,252	$424
Liabilities:	'	'	'
Derivative Liabilities	238	135	15,224
Commodity Contract | Fair Value, Measurements, Recurring	'	'	'
Assets:	'	'	'
Derivative Assets	4,862	18,252	424
Liabilities:	'	'	'
Derivative Liabilities	238	135	15,224
Commodity Contract | Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1) | Fair Value, Measurements, Recurring	'	'	'
Assets:	'	'	'
Derivative Assets	0	0	0
Liabilities:	'	'	'
Derivative Liabilities	0	0	0
Commodity Contract | Significant Other Observable Inputs (Level 2) | Fair Value, Measurements, Recurring	'	'	'
Assets:	'	'	'
Derivative Assets	4,862	18,252	424
Liabilities:	'	'	'
Derivative Liabilities	238	135	15,224
Commodity Contract | Unobservable Inputs (Level 3) | Fair Value, Measurements, Recurring	'	'	'
Assets:	'	'	'
Derivative Assets	0	0	0
Liabilities:	'	'	'
Derivative Liabilities	$0	$0	$0

Fair_Value_Measurement_Fair_Va1

Fair Value Measurement - Fair Value by Balance Sheet Grouping (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2013
In Thousands, unless otherwise specified
Fair Value Disclosures [Abstract]	'	'	'
Derivative Assets, Fair Value, Gross	$8,068	$19,621	$424
Derivative Asset, Offset Amount, Gross	-3,206	-1,369	0
Derivative Assets	4,862	18,252	424
Derivative Liabilities, Fair Value, Gross	-3,444	-1,504	-15,224
Derivative Liability, Offset Amount, Gross	3,206	1,369	0
Derivative Liabilities	$238	$135	$15,224

Disclosures_About_Derivative_I1

Disclosures About Derivative Instruments and Hedging Activities - Narrative (Details) (USD $)	0 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2013
		gal	gal
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'
Derivative, Nonmonetary Notional Amount	'	210,300,000	177,800,000
Maximum Length of Time Hedged in Price Risk Cash Flow Hedge (in months)	'	'24 months	'
Weighted Average Length of Time Hedge in Price Risk Cash Flow Hedge (in months)	'7 months	'	'
Net losses associated with commodity price risk hedges expected to be reclassified into earnings during the next twelve months	'	$4,772	'

Disclosures_About_Derivative_I2

Disclosures About Derivative Instruments and Hedging Activities - Components of Fair Value of Derivative Assets and Liabilities (Details) (USD $)	Jun. 30, 2014	Sep. 30, 2013	Jun. 30, 2013
In Thousands, unless otherwise specified
Derivative Assets, Fair Value	'	'	'
Amounts above offset in the Balance Sheet	($1,829)	'	$0
Derivative Liability, Offset Amount, Net	1,829	'	0
Total Derivative Assets	4,862	18,252	424
Derivative Liabilities, Fair Value	'	'	'
Total Derivative Liabilities	-238	-135	-15,224
Designated as Hedging Instrument | Propane contracts | Derivative Financial Instruments and Other Assets	'	'	'
Derivative Assets, Fair Value	'	'	'
Derivative Assets	6,378	'	424
Designated as Hedging Instrument | Propane contracts | Derivative Financial Instruments and Other Non Current Liabilities	'	'	'
Derivative Liabilities, Fair Value	'	'	'
Derivative Liabilities	0	'	-15,224
Not Designated as Hedging Instrument | Propane contracts | Derivative financial instruments	'	'	'
Derivative Assets, Fair Value	'	'	'
Derivative Assets	313	'	0
Derivative Liabilities, Fair Value	'	'	'
Derivative Liabilities	($2,067)	'	$0

Disclosures_About_Derivative_I3

Disclosures About Derivative Instruments and Hedging Activities - Components of Derivative Instruments Gain Loss in Statement of Operations (Details) (Propane contracts, Cost of sales - propane, USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Designated as Hedging Instrument	'	'	'	'
Derivative Instruments, Gain (Loss)	'	'	'	'
Gain (Loss) Recognized in AOCI and Noncontrolling Interest	$884	($19,434)	$46,231	($24,348)
Gain (Loss) Reclassified from AOCI and Noncontrolling Interest into Income	5,258	-8,479	53,685	-51,229
Not Designated as Hedging Instrument	'	'	'	'
Derivative Instruments, Gain (Loss)	'	'	'	'
Derivative Instruments, Gain (Loss) Recognized in Income, Net	($2,006)	$0	$4,924	$0

Error_in_Accounting_for_Certai1

Error in Accounting for Certain Customer Credits - Narrative (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Immaterial Error Correction	'	'	'4200	'
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	$37,749	$34,549	($341,873)	($279,275)
Restatement Adjustment	'	'	'	'
Accounts Receivable and Propane Revenues	'	'	'	7,038
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest	'	'	'	$6,967

Debt_Details

Debt (Details) (Line of Credit, USD $)	9 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Debt Instrument	'
Maximum borrowing capacity	525
Credit Agreement | Minimum	'
Debt Instrument	'
Commitment fee percentage	0.30%
Credit Agreement | Maximum	'
Debt Instrument	'
Commitment fee percentage	0.50%
Credit Agreement | Base Rate | Minimum	'
Debt Instrument	'
Applicable margin	0.80%
Credit Agreement | Base Rate | Maximum	'
Debt Instrument	'
Applicable margin	1.80%
Credit Agreement | Eurodollar | Minimum	'
Debt Instrument	'
Applicable margin	1.80%
Credit Agreement | Eurodollar | Maximum	'
Debt Instrument	'
Applicable margin	2.80%
Amended and Restated Credit Agreement | Minimum	'
Debt Instrument	'
Commitment fee percentage	0.30%
Amended and Restated Credit Agreement | Maximum	'
Debt Instrument	'
Commitment fee percentage	0.45%
Amended and Restated Credit Agreement | Federal Funds Rate	'
Debt Instrument	'
Applicable margin	0.50%
Amended and Restated Credit Agreement | Base Rate | Minimum	'
Debt Instrument	'
Applicable margin	0.50%
Amended and Restated Credit Agreement | Base Rate | Maximum	'
Debt Instrument	'
Applicable margin	1.50%
Amended and Restated Credit Agreement | Eurodollar | Minimum	'
Debt Instrument	'
Applicable margin	1.50%
Amended and Restated Credit Agreement | Eurodollar | Maximum	'
Debt Instrument	'
Applicable margin	2.50%
Letter of Credit	'
Debt Instrument	'
Maximum borrowing capacity	125