AmeriGas Partners (APU) 10-Q 5 Aug 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Jun. 30, 2016	Jul. 31, 2016
Document and Entity Information [Abstract]
Entity Registrant Name	AMERIGAS PARTNERS LP
Entity Central Index Key	932,628
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--09-30
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		92,923,410

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (unaudited) - USD ($) $ in Thousands	Jun. 30, 2016	Sep. 30, 2015	Jun. 30, 2015
Current assets:
Cash and cash equivalents	$ 307,657	$ 14,757	$ 16,222
Accounts receivable (less allowances for doubtful accounts of $11,952, $12,257 and $16,007, respectively)	187,551	199,067	223,228
Accounts receivable - related parties	3,108	2,360	3,187
Inventories	81,571	93,934	93,301
Derivative instruments	8,968	0	0
Prepaid expenses and other current assets	50,836	56,243	49,981
Total current assets	639,691	366,361	385,919
Property, plant and equipment (less accumulated depreciation and amortization of $1,468,332, $1,369,733 and $1,333,992, respectively)	1,285,518	1,324,327	1,341,325
Goodwill	1,978,894	1,956,688	1,954,791
Intangible assets, net	420,473	433,713	441,349
Derivative instruments	891	0	0
Other assets	71,772	60,623	62,364
Total assets	4,397,239	4,141,712	4,185,748
Current liabilities:
Current maturities of long-term debt	361,177	9,679	10,353
Short-term borrowings	11,400	68,100	43,600
Accounts payable - trade	81,358	101,588	100,634
Accounts payable - related parties	684	445	39
Customer deposits and advances	79,174	117,087	61,412
Derivative instruments	4,562	47,507	47,514
Other current liabilities	178,173	201,888	178,627
Total current liabilities	716,528	546,294	442,179
Long-term debt	2,356,908	2,273,817	2,279,237
Derivative instruments	963	7,670	8,660
Other noncurrent liabilities	116,855	113,558	109,252
Total liabilities	3,191,254	2,941,339	2,839,328
Commitments and contingencies
AmeriGas Partners, L.P. partners’ capital:
Common unitholders (units issued - 92,922,926, 92,889,980 and 92,889,543, respectively)	1,150,641	1,145,291	1,288,367
General partner	19,004	18,925	20,369
Accumulated other comprehensive income	0	0	301
Total AmeriGas Partners, L.P. partners’ capital	1,169,645	1,164,216	1,309,037
Noncontrolling interest	36,340	36,157	37,383
Total partners’ capital	1,205,985	1,200,373	1,346,420
Total liabilities and partners’ capital	$ 4,397,239	$ 4,141,712	$ 4,185,748

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2016	Sep. 30, 2015	Jun. 30, 2015
Statement of Financial Position [Abstract]
Accounts receivable, allowances for doubtful accounts	$ 11,952	$ 12,257	$ 16,007
Property, plant and equipment, accumulated depreciation and amortization	$ 1,468,332	$ 1,369,733	$ 1,333,992
Common unitholders, units issued (in units)	92,922,926	92,889,980	92,889,543

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations (unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues:
Propane	$ 385,566	$ 414,146	$ 1,718,748	$ 2,254,961
Other	61,118	63,831	199,521	212,125
Total, Revenues	446,684	477,977	1,918,269	2,467,086
Costs and expenses:
Cost of sales - propane (excluding depreciation shown below)	121,812	172,803	591,355	1,163,089
Cost of sales - other (excluding depreciation shown below)	21,145	23,745	59,173	64,607
Operating and administrative expenses	217,154	223,306	686,578	727,303
Depreciation	35,668	37,370	110,807	113,454
Amortization	10,742	10,666	32,228	32,065
Other operating income, net	(6,041)	(5,548)	(22,079)	(23,088)
Total, costs and expenses	400,480	462,342	1,458,062	2,077,430
Operating income	46,204	15,635	460,207	389,656
Loss on extinguishments of debt	(37,086)	0	(37,086)	0
Interest expense	(40,838)	(40,274)	(122,669)	(122,404)
(Loss) income before income taxes	(31,720)	(24,639)	300,452	267,252
Income tax expense	(907)	(802)	(2,107)	(2,478)
Net (loss) income including noncontrolling interest	(32,627)	(25,441)	298,345	264,774
Deduct net income attributable to noncontrolling interest	(442)	(137)	(4,533)	(3,868)
Net (loss) income attributable to AmeriGas Partners, L.P.	(33,069)	(25,578)	293,812	260,906
General partner’s interest in net (loss) income attributable to AmeriGas Partners, L.P.	10,101	8,389	30,663	24,321
Limited partners’ interest in net (loss) income attributable to AmeriGas Partners, L.P.	$ (43,170)	$ (33,967)	$ 263,149	$ 236,585
(Loss) income per limited partner unit - basic and diluted:
Basic (in usd per unit)	$ (0.46)	$ (0.37)	$ 2.81	$ 2.53
Diluted (in usd per unit)	$ (0.46)	$ (0.37)	$ 2.80	$ 2.53
Weighted average limited partner units outstanding (thousands):
Basic (in units)	92,960	92,918	92,945	92,908
Diluted (in units)	92,960	92,918	93,019	92,972

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Comprehensive Income (unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Net (loss) income including noncontrolling interest	$ (32,627)	$ (25,441)	$ 298,345	$ 264,774
Other comprehensive loss:
Reclassifications of net gains on derivative instruments	0	(213)	0	(2,518)
Other comprehensive loss	0	(213)	0	(2,518)
Total comprehensive (loss) income including noncontrolling interest	(32,627)	(25,654)	298,345	262,256
Deduct comprehensive income attributable to noncontrolling interest	(442)	(135)	(4,533)	(3,843)
Comprehensive (loss) income attributable to AmeriGas Partners, L.P.	$ (33,069)	$ (25,789)	$ 293,812	$ 258,413

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Cash Flows (unaudited) - USD ($) $ in Thousands	9 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income including noncontrolling interest	$ 298,345	$ 264,774
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	143,035	145,519
Provision for uncollectible accounts	9,354	13,791
Unrealized (gains) losses on derivative instruments	(61,671)	48,678
Loss on extinguishments of debt	37,086	0
Other, net	649	(3,774)
Net change in:
Accounts receivable	427	29,700
Inventories	12,609	86,606
Accounts payable	(22,105)	(51,564)
Other current assets	10,610	(5,827)
Other current liabilities	(65,937)	(103,852)
Net cash provided by operating activities	362,402	424,051
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(74,472)	(77,858)
Proceeds from disposals of assets	11,230	18,380
Acquisitions of businesses, net of cash acquired	(36,678)	(17,008)
Net cash used by investing activities	(99,920)	(76,486)
CASH FLOWS FROM FINANCING ACTIVITIES
Distributions	(288,891)	(273,372)
Noncontrolling interest activity	(4,350)	(4,836)
Decrease in short-term borrowings	(56,700)	(65,400)
Issuances of long-term debt	1,333,407	0
Repayments of long-term debt	(954,186)	(4,698)
Proceeds associated with equity-based compensation plans, net of tax withheld	1,127	3,449
Capital contributions from General Partner	11	34
Net cash provided (used) by financing activities	30,418	(344,823)
Cash and cash equivalents increase	292,900	2,742
CASH AND CASH EQUIVALENTS
End of period	307,657	16,222
Beginning of period	14,757	13,480
Increase	$ 292,900	$ 2,742

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Partners' Capital (unaudited) - USD ($) $ in Thousands	Total	Total AmeriGas Partners, L.P. Partners' Capital	Common Units	General Partner	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interest
Beginning Balance (in units) at Sep. 30, 2014			92,867,204
Beginning Balance (in usd) at Sep. 30, 2014	$ 1,360,890	$ 1,322,514	$ 1,299,260	$ 20,460	$ 2,794	$ 38,376
Increase (Decrease) in Partners' Capital
Net income	264,774	260,906	236,585	24,321		3,868
Reclassifications of net gains on derivative instruments	(2,518)	(2,493)			(2,493)	(25)
Distributions	(277,564)	(273,372)	(248,926)	(24,446)		(4,192)
Unit-based compensation expense	1,999	1,999	$ 1,999
Common Units issued in connection with employee and director plans, net of tax withheld (in units)			22,339
Common Units issued in connection with employee and director plans, net of tax withheld	(517)	(517)	$ (551)	34
Distribution related to common control transaction	(644)					(644)
Ending Balance (in units) at Jun. 30, 2015			92,889,543
Ending Balance (in usd) at Jun. 30, 2015	1,346,420	1,309,037	$ 1,288,367	20,369	301	37,383
Beginning Balance (in units) at Sep. 30, 2015			92,889,980
Beginning Balance (in usd) at Sep. 30, 2015	1,200,373	1,164,216	$ 1,145,291	18,925	0	36,157
Increase (Decrease) in Partners' Capital
Net income	298,345	293,812	263,149	30,663		4,533
Reclassifications of net gains on derivative instruments	0
Distributions	(293,241)	(288,891)	(258,296)	(30,595)		(4,350)
Unit-based compensation expense	1,070	1,070	$ 1,070
Common Units issued in connection with employee and director plans, net of tax withheld (in units)			32,946
Common Units issued in connection with employee and director plans, net of tax withheld	(562)	(562)	$ (573)	11
Ending Balance (in units) at Jun. 30, 2016			92,922,926
Ending Balance (in usd) at Jun. 30, 2016	$ 1,205,985	$ 1,169,645	$ 1,150,641	$ 19,004	$ 0	$ 36,340

Nature of Operations

Nature of Operations	9 Months Ended
	Jun. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Operations	Note 1 — 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”), which is referred to herein as the “Operating Partnership.” AmeriGas Partners and AmeriGas OLP are Delaware limited partnerships. AmeriGas Partners, the Operating Partnership and all of their 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, 2016 , 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 owns AmeriGas Partners Common Units (“Common Units”). The remaining Common Units outstanding represents publicly held Common Units. Common Units represent limited partner interests in AmeriGas Partners. AmeriGas Partners holds a 98.99% limited partner interest in AmeriGas OLP. AmeriGas Partners and the Operating Partnership have no employees. Employees of the General Partner conduct, direct and manage our operations. The General Partner is reimbursed monthly for all direct and indirect expenses it incurs on our behalf (see Note 9 ).

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2 — Summary of Significant Accounting Policies 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, 2015 , 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, 2015 (“the Partnership’s 2015 Annual Report”). 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 . 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, L.P., as amended (“Partnership Agreement”). Net Income (Loss) Per Unit. Income (loss) per limited partner unit is computed in accordance with GAAP regarding the application of the two-class method for determining income (loss) 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 2016 2015 2016 2015 Net (loss) income attributable to AmeriGas Partners, L.P. $ (33,069 ) $ (25,578 ) $ 293,812 $ 260,906 Adjust for general partner share and theoretical distributions of net (loss) income attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs (10,101 ) (8,389 ) (33,039 ) (25,695 ) Common Unitholders’ interest in net (loss) income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs $ (43,170 ) $ (33,967 ) $ 260,773 $ 235,211 Weighted average Common Units outstanding—basic (thousands) 92,960 92,918 92,945 92,908 Potentially dilutive Common Units (thousands) — — 74 64 Weighted average Common Units outstanding—diluted (thousands) 92,960 92,918 93,019 92,972 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, 2016 and 2015 , 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 $0.03 and $0.01 , 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, 2016 and 2015 . 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. Derivative Instruments. Derivative instruments are reported on the Condensed Consolidated Balance Sheets at their fair values, unless the derivative instruments qualify for the normal purchase and normal sale (“NPNS”) exception under GAAP. The accounting for changes in fair value depends upon the purpose of the derivative instrument and whether it is designated and qualifies for hedge accounting. Effective April 1, 2014, the Partnership determined that on a prospective basis, it would no longer elect cash flow hedge accounting for its commodity derivative instruments. Effective October 1, 2014, the Partnership de-designated its remaining commodity derivative instruments accounted for as cash flow hedges. As a result, changes in the fair values of commodity derivative instruments for all periods presented are reflected in cost of sales - propane on the Condensed Consolidated Statements of Operations. Cash flows from derivative instruments are included in cash flows from operating activities. At June 30, 2016, there were no amounts remaining in accumulated other comprehensive income (loss) (“AOCI”) related to commodity derivative instruments. For additional information on the accounting for our derivative instruments, see Note 2, “Summary of Significant Accounting Policies,” in the Partnership’s 2015 Annual Report. 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, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Accounting Changes	Note 3 — Accounting Changes Accounting Standards Not Yet Adopted Leases. In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02, "Leases." This ASU amends existing guidance to require entities that lease assets to recognize the assets and liabilities for the rights and obligations created by those leases on the balance sheet. The new guidance also requires additional disclosures about the amount, timing and uncertainty of cash flows from leases. The amendments in this ASU are effective for annual reporting periods beginning after December 15, 2018 (Fiscal 2020). Early adoption is permitted. Lessees must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The Partnership is in the process of assessing the impact on its financial statements from the adoption of the new guidance but anticipates an increase in the recognition of right-of-use assets and lease liabilities. Debt Issuance Costs. In April 2015, the FASB issued ASU No. 2015-03, "Simplifying the Presentation of Debt Issuance Costs." This ASU amends existing guidance to require the presentation of debt issuance costs in the balance sheet as a direct deduction from the carrying amount of the related debt liability instead of a deferred charge. The amendments in this ASU are effective for annual reporting periods beginning after December 15, 2015 (Fiscal 2017). Early adoption is permitted. Entities will apply the new guidance retrospectively to all periods presented. The Partnership expects to adopt the new guidance effective September 30, 2016. The adoption of the new guidance is not expected to have a material impact on the Partnership’s financial statements. Consolidation. In February 2015, the FASB issued ASU No. 2015-02, “Amendments to the Consolidation Analysis.” This ASU provides new guidance regarding whether a reporting entity should consolidate certain types of legal entities. Among other things, the new guidance modifies the evaluation of whether limited partnerships and similar entities are variable interest entities (“VIEs”) or voting interest entities, and also eliminates the presumption that a general partner should consolidate a limited partnership. The new guidance also affects the consolidation analysis of reporting entities that are involved with VIEs including those that have fee arrangements and related party relationships. The new guidance is effective for the Partnership beginning in Fiscal 2017. Early adoption is permitted. The Partnership is in the process of assessing the impact on its financial statements, if any, from the adoption of the new guidance. Revenue Recognition. In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers.” The guidance provided under this ASU, as amended, supersedes the revenue recognition requirements in Accounting Standards Codification (“ASC”) 605, “Revenue Recognition,” and most industry-specific guidance included in the ASC. 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 entity expects to be entitled in exchange for those goods or services. The new guidance is effective for the Partnership for interim and annual periods beginning after December 15, 2017 (Fiscal 2019) and allows for either full retrospective adoption or modified retrospective adoption. We have not yet selected a transition method and are currently evaluating the impact of adopting this guidance on our consolidated financial statements.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	9 Months Ended
	Jun. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	Note 4 — Goodwill and Intangible Assets The Partnership’s goodwill and intangible assets comprise the following: June 30, September 30, June 30, Goodwill (not subject to amortization) $ 1,978,894 $ 1,956,688 $ 1,954,791 Intangible assets: Customer relationships and noncompete agreements $ 529,739 $ 514,333 $ 512,552 Accumulated amortization (192,210 ) (163,564 ) (154,147 ) Intangible assets, net (definite-lived) 337,529 350,769 358,405 Trademarks and tradenames (indefinite-lived) 82,944 82,944 82,944 Total intangible assets, net $ 420,473 $ 433,713 $ 441,349 Amortization expense of intangible assets was $9,545 and $9,473 for the three months ended June 30, 2016 and 2015 , respectively. Amortization expense of intangible assets was $28,646 and $28,487 for the nine months ended June 30, 2016 and 2015 , respectively. No amortization expense is included in cost of sales on the Condensed Consolidated Statements of Operations. The estimated aggregate amortization expense of intangible assets for the remainder of Fiscal 2016 and the next four fiscal years is as follows: remainder of Fiscal 2016 — $9,737 ; Fiscal 2017 — $37,148 ; Fiscal 2018 — $35,788 ; Fiscal 2019 — $34,592 ; Fiscal 2020 — $33,410 .

Debt

Debt	9 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Debt	Note 5 — Debt On June 27, 2016, AmeriGas Partners and AmeriGas Finance Corp., a 100% wholly owned finance subsidiary of AmeriGas Partners, (the “Issuers”) issued $675,000 principal amount of 5.625% Senior Notes due May 2024 (the “ 5.625% Senior Notes”) and $675,000 principal amount of 5.875% Senior Notes due August 2026 (the “ 5.875% Senior Notes”) (collectively, the “Senior Notes”). The Senior Notes rank equally with AmeriGas Partners’ existing outstanding senior notes. On June 20, 2016, AmeriGas Partners announced cash tender offers to purchase all of AmeriGas Partners’ 6.50% Senior Notes, 6.75% Senior Notes and 6.25% Senior Notes (collectively, the “Tendered Notes”). A portion of the proceeds from the issuance of the previously mentioned Senior Notes, net of underwriters’ discounts and offering expenses, were used on June 27, 2016, to redeem Tendered Notes having an aggregate principal amount of $917,143 , plus tender premiums and accrued and unpaid interest. The remaining net proceeds from the issuance of the Senior Notes were used in July, and will be used in August 2016 to redeem the senior notes not repaid on June 27, 2016 (as further described below) and for general corporate purposes. The aggregate principal amounts of the Tendered Notes subject to the tender offers, the associated amounts repaid on June 27, 2016, and the remaining amounts outstanding as of June 30, 2016, are as follows: Notes Aggregate Principal Amounts Amounts Repaid on June 27, 2016 Remaining Amounts Outstanding at June 30, 2016 6.50% Senior Notes due May 2021 $ 270,001 $ 203,476 $ 66,525 6.75% Senior Notes due May 2020 550,000 406,946 143,054 6.25% Senior Notes due August 2019 450,000 306,721 143,279 Total $ 1,270,001 $ 917,143 $ 352,858 In June 2016, the Partnership recognized a loss of $37,086 associated with the senior notes repaid on June 27, 2016, pursuant to the tender offers, primarily comprising $29,676 of tender premiums and the write-off of $6,748 of debt issuance costs. The loss is reflected in “Loss on extinguishments of debt” on the Condensed Consolidated Statements of Operations. On June 27, 2016, AmeriGas Partners issued a notice of cash redemption for the remaining 6.50% Senior Notes, 6.75% Senior Notes, and 6.25% Senior Notes not previously tendered, plus call premiums and accrued and unpaid interest. The redemption date for the 6.75% Senior Notes and the 6.50% Senior Notes was July 27, 2016, and the redemption date for the 6.25% Senior Notes is August 22, 2016. These senior notes have been included in “Current maturities of long-term debt” on the June 30, 2016, Condensed Consolidated Balance Sheet. The Partnership expects to recognize a loss on extinguishment of debt of approximately $12,000 during the fourth quarter of Fiscal 2016 associated with these redemptions.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 6 — Commitments and Contingencies Contingencies Purported Class Action Lawsuits. Between May and October of 2014, more than 35 purported class action lawsuits were filed in multiple jurisdictions against the Partnership/UGI and a competitor by certain of their direct and indirect customers. The class action lawsuits allege, among other things, that the Partnership and its competitor colluded, beginning in 2008, to reduce the fill level of portable propane cylinders from 17 pounds to 15 pounds and combined to persuade their 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. On October 16, 2014, the United States Judicial Panel on Multidistrict Litigation transferred all of these purported class action cases to the Western Division of the United States District Court for the Western District of Missouri. In July 2015, the Court dismissed all claims brought by direct customers and all claims other than those for injunctive relief brought by indirect customers. The direct customers filed an appeal with the United States Court of Appeals for the Eighth Circuit, which is still pending. The indirect customers filed an amended complaint claiming injunctive relief and state law claims under Wisconsin, Maine and Vermont law. In January 2016, the District Court dismissed the remaining injunctive relief claims for the indirect purchasers. As a result, the only claims remaining with respect to indirect purchasers involve alleged violations of Wisconsin, Maine and Vermont state antitrust laws. On July 21, 2016, several new indirect purchaser plaintiffs filed an antitrust class action lawsuit against the Partnership in the Western District of Missouri. This lawsuit repeats the allegations and claims from the existing indirect purchaser complaints, includes several of the same plaintiffs and was filed by the same group of lawyers. 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 financial position, results of operations or cash flows.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 7 — Fair Value Measurements Derivative Instruments The following table presents on a gross basis our derivative assets and liabilities including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy, as of June 30, 2016 , September 30, 2015 and June 30, 2015 : Asset (Liability) Level 1 Level 2 Level 3 Total June 30, 2016: Assets: Propane contracts $ — $ 14,063 $ — $ 14,063 Liabilities: Propane contracts $ — $ (9,729 ) $ — $ (9,729 ) September 30, 2015: Assets: Propane contracts $ — $ 1,242 $ — $ 1,242 Liabilities: Propane contracts $ — $ (58,579 ) $ — $ (58,579 ) June 30, 2015: Assets: Propane contracts $ — $ 308 $ — $ 308 Liabilities: Propane contracts $ — $ (58,482 ) $ — $ (58,482 ) 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, if any, 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, 2016 , the carrying amount and estimated fair value of our long-term debt (including current maturities) were $2,718,085 and $2,774,520 , respectively. At June 30, 2015 , the carrying amount and estimated fair value of our long-term debt (including current maturities) were $2,289,590 and $2,402,239 , 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). Financial instruments other than derivative instruments, such as short-term investments and trade accounts receivable, could expose us to concentrations of credit risk. We limit credit risk from short-term investments by investing only in investment-grade commercial paper, money market mutual funds, securities guaranteed by the U.S. Government or its agencies and FDIC insured bank deposits. The credit risk arising from concentrations of trade accounts receivable is limited because we have a large customer base that extends across many different U.S. markets.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	9 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	Note 8 — 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 risks managed by derivative instruments are commodity price risk and interest rate risk. 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. Although our commodity derivative instruments extend over a number of years, a significant portion of our commodity derivative instruments economically hedge commodity price risk during the next twelve months. Commodity Price Risk In order to manage market risk associated with the Partnership’s fixed-price programs, the Partnership uses over-the-counter derivative commodity instruments, principally price swap contracts. In addition, the Partnership uses over-the-counter price swap and option contracts to reduce propane price volatility associated with a portion of forecasted propane purchases. In addition, the Partnership from time to time enters into price swap and put option agreements to reduce the effects of short-term commodity price volatility . At June 30, 2016 and 2015 , total volumes associated with propane commodity derivatives totaled 259.4 million gallons and 292.7 million gallons, respectively. At June 30, 2016 , the maximum period over which we are economically hedging propane market price risk is 39 months . Derivative 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 comprise 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. Although we have concentrations of credit risk associated with derivative instruments held by certain derivative instrument counterparties, the maximum amount of loss due to credit risk that, based upon the gross fair values of the derivative instruments, we would incur if these counterparties that make up the concentration failed to perform according to the terms of their contracts was not material at June 30, 2016 . 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, 2016 , if the credit-risk-related contingent features were triggered, the amount of collateral required to be posted would not be material. Offsetting Derivative Assets and Liabilities Derivative assets and liabilities (and cash collateral received and pledged) are presented net by counterparty on our Condensed Consolidated Balance Sheets if the right of offset exists. Our derivative instruments comprise over-the-counter transactions. 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, the contracts are 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. Types of collateral generally include cash or letters of credit. Cash collateral paid by us to our over-the-counter derivative counterparties, if any, is reflected in the table below to offset derivative liabilities. Cash collateral received by us from our over-the-counter derivative 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 table below but could reduce our net exposure to such counterparties because such balances are subject to master netting or similar arrangements. Fair Value of Derivative Instruments The following table presents our derivative assets and liabilities, as well as the effects of offsetting, as of June 30, 2016 and 2015 : June 30, June 30, Derivative assets not designated as hedging instruments: Propane contracts $ 14,063 $ 308 Total derivative assets - gross 14,063 308 Gross amounts offset in the balance sheet (4,204 ) (308 ) Total derivative assets - net $ 9,859 $ — Derivative liabilities not designated as hedging instruments: Propane contracts $ (9,729 ) $ (58,482 ) Total derivative liabilities - gross (9,729 ) (58,482 ) Gross amounts offset in the balance sheet 4,204 308 Cash collateral pledged — 2,000 Total derivative liabilities - net $ (5,525 ) $ (56,174 ) Effect of Derivative Instruments The following tables provide 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, 2016 and 2015 : Gain Location of Gain Three Months Ended June 30, 2016 2015 Cash Flow Hedges: Propane contracts $ — $ 213 Cost of sales - propane Gain (Loss) Location of Gain (Loss) Three Months Ended June 30, 2016 2015 Derivatives Not Designated as Hedging Instruments: Propane contracts $ 20,409 $ (12,216 ) Cost of sales - propane Gain Location of Gain Nine Months Ended June 30, 2016 2015 Cash Flow Hedges: Propane contracts $ — $ 2,518 Cost of sales - propane Gain (Loss) Recognized in Income Location of Gain (Loss) Nine Months Ended June 30, 2016 2015 Derivatives Not Designated as Hedging Instruments: Propane contracts $ 4,579 $ (192,701 ) Cost of sales - propane 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, contracts that 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.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Jun. 30, 2016
Related Party Transactions [Abstract]
Related Party Transactions	Note 9 — Related Party Transactions Pursuant to the Partnership Agreement and a management services agreement, the General Partner is entitled to reimbursement for all direct and indirect expenses incurred or payments it makes on behalf of the Partnership. These costs, which totaled $129,773 and $135,631 for the three months ended June 30, 2016 and 2015 , respectively, and $431,314 and $440,946 for the nine months ended June 30, 2016 and 2015 , 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 $4,392 and $5,024 for the three months ended June 30, 2016 and 2015 , respectively, and $13,784 and $18,126 during the nine months ended June 30, 2016 and 2015 , 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 $595 and $711 for the three months ended June 30, 2016 and 2015 , respectively, and $1,843 and $2,171 for the nine months ended June 30, 2016 and 2015 , respectively. From time to time, AmeriGas OLP purchases propane on an as needed basis from UGI Energy Services, LLC (“Energy Services”). The price of the purchases are generally based on the market price at the time of purchase. There were no purchases of propane by AmeriGas OLP from Energy Services during the three and nine months ended June 30, 2016 and 2015 . In addition, the Partnership sells propane to affiliates of UGI. Sales of propane to affiliates of UGI totaled $30 and $97 for the three months ended June 30, 2016 and 2015 , respectively, and $335 and $1,190 for the nine months ended June 30, 2016 and 2015 , respectively. Pursuant to an Asset Sale and Purchase Agreement, on October 13, 2014, AmeriGas OLP purchased from UGI HVAC Enterprises, Inc. (“HVAC”), a second-tier, wholly owned subsidiary of UGI, a residential heating, ventilation, air conditioning, plumbing and related services business for $2,000 cash. Because the transaction was between entities under common control, the purchase price in excess of the carrying value of assets transferred was considered an equity transaction and has been recorded as a distribution on the Condensed Consolidated Statements of Partners’ Capital. In connection with this transaction, AmeriGas OLP entered into a Shared Service Agreement (“SSA”) whereby HVAC provides certain financial and administrative services to the Partnership with respect to the business purchased. Expenses associated with the SSA totaled $256 and $768 during the three and nine months ended June 30, 2016 , respectively, and $256 and $734 during the three and nine months ended June 30, 2015 , respectively.

Summary of Significant Accoun17

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Allocation of Net Income	Allocation of Net Income . 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, L.P., as amended (“Partnership Agreement”).
Net Income (Loss) Per Unit	Net Income (Loss) Per Unit. Income (loss) per limited partner unit is computed in accordance with GAAP regarding the application of the two-class method for determining income (loss) 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).
Derivative Instruments	Derivative Instruments. Derivative instruments are reported on the Condensed Consolidated Balance Sheets at their fair values, unless the derivative instruments qualify for the normal purchase and normal sale (“NPNS”) exception under GAAP. The accounting for changes in fair value depends upon the purpose of the derivative instrument and whether it is designated and qualifies for hedge accounting. Effective April 1, 2014, the Partnership determined that on a prospective basis, it would no longer elect cash flow hedge accounting for its commodity derivative instruments. Effective October 1, 2014, the Partnership de-designated its remaining commodity derivative instruments accounted for as cash flow hedges. As a result, changes in the fair values of commodity derivative instruments for all periods presented are reflected in cost of sales - propane on the Condensed Consolidated Statements of Operations. Cash flows from derivative instruments are included in cash flows from operating activities. At June 30, 2016, there were no amounts remaining in accumulated other comprehensive income (loss) (“AOCI”) related to commodity derivative instruments. For additional information on the accounting for our derivative instruments, see Note 2, “Summary of Significant Accounting Policies,” in the Partnership’s 2015 Annual Report.
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.
Accounting Standards Not Yet Adopted	Accounting Standards Not Yet Adopted Leases. In February 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-02, "Leases." This ASU amends existing guidance to require entities that lease assets to recognize the assets and liabilities for the rights and obligations created by those leases on the balance sheet. The new guidance also requires additional disclosures about the amount, timing and uncertainty of cash flows from leases. The amendments in this ASU are effective for annual reporting periods beginning after December 15, 2018 (Fiscal 2020). Early adoption is permitted. Lessees must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The Partnership is in the process of assessing the impact on its financial statements from the adoption of the new guidance but anticipates an increase in the recognition of right-of-use assets and lease liabilities. Debt Issuance Costs. In April 2015, the FASB issued ASU No. 2015-03, "Simplifying the Presentation of Debt Issuance Costs." This ASU amends existing guidance to require the presentation of debt issuance costs in the balance sheet as a direct deduction from the carrying amount of the related debt liability instead of a deferred charge. The amendments in this ASU are effective for annual reporting periods beginning after December 15, 2015 (Fiscal 2017). Early adoption is permitted. Entities will apply the new guidance retrospectively to all periods presented. The Partnership expects to adopt the new guidance effective September 30, 2016. The adoption of the new guidance is not expected to have a material impact on the Partnership’s financial statements. Consolidation. In February 2015, the FASB issued ASU No. 2015-02, “Amendments to the Consolidation Analysis.” This ASU provides new guidance regarding whether a reporting entity should consolidate certain types of legal entities. Among other things, the new guidance modifies the evaluation of whether limited partnerships and similar entities are variable interest entities (“VIEs”) or voting interest entities, and also eliminates the presumption that a general partner should consolidate a limited partnership. The new guidance also affects the consolidation analysis of reporting entities that are involved with VIEs including those that have fee arrangements and related party relationships. The new guidance is effective for the Partnership beginning in Fiscal 2017. Early adoption is permitted. The Partnership is in the process of assessing the impact on its financial statements, if any, from the adoption of the new guidance. Revenue Recognition. In May 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers.” The guidance provided under this ASU, as amended, supersedes the revenue recognition requirements in Accounting Standards Codification (“ASC”) 605, “Revenue Recognition,” and most industry-specific guidance included in the ASC. 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 entity expects to be entitled in exchange for those goods or services. The new guidance is effective for the Partnership for interim and annual periods beginning after December 15, 2017 (Fiscal 2019) and allows for either full retrospective adoption or modified retrospective adoption. We have not yet selected a transition method and are currently evaluating the impact of adopting this guidance on our consolidated financial statements.

Summary of Significant Accoun18

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Jun. 30, 2016
Accounting Policies [Abstract]
Schedule of 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 2016 2015 2016 2015 Net (loss) income attributable to AmeriGas Partners, L.P. $ (33,069 ) $ (25,578 ) $ 293,812 $ 260,906 Adjust for general partner share and theoretical distributions of net (loss) income attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs (10,101 ) (8,389 ) (33,039 ) (25,695 ) Common Unitholders’ interest in net (loss) income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs $ (43,170 ) $ (33,967 ) $ 260,773 $ 235,211 Weighted average Common Units outstanding—basic (thousands) 92,960 92,918 92,945 92,908 Potentially dilutive Common Units (thousands) — — 74 64 Weighted average Common Units outstanding—diluted (thousands) 92,960 92,918 93,019 92,972

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	9 Months Ended
	Jun. 30, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Components of Goodwill and Intangible Assets	The Partnership’s goodwill and intangible assets comprise the following: June 30, September 30, June 30, Goodwill (not subject to amortization) $ 1,978,894 $ 1,956,688 $ 1,954,791 Intangible assets: Customer relationships and noncompete agreements $ 529,739 $ 514,333 $ 512,552 Accumulated amortization (192,210 ) (163,564 ) (154,147 ) Intangible assets, net (definite-lived) 337,529 350,769 358,405 Trademarks and tradenames (indefinite-lived) 82,944 82,944 82,944 Total intangible assets, net $ 420,473 $ 433,713 $ 441,349

Debt (Tables)

Debt (Tables)	9 Months Ended
	Jun. 30, 2016
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	The aggregate principal amounts of the Tendered Notes subject to the tender offers, the associated amounts repaid on June 27, 2016, and the remaining amounts outstanding as of June 30, 2016, are as follows: Notes Aggregate Principal Amounts Amounts Repaid on June 27, 2016 Remaining Amounts Outstanding at June 30, 2016 6.50% Senior Notes due May 2021 $ 270,001 $ 203,476 $ 66,525 6.75% Senior Notes due May 2020 550,000 406,946 143,054 6.25% Senior Notes due August 2019 450,000 306,721 143,279 Total $ 1,270,001 $ 917,143 $ 352,858

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Financial Assets and Financial Liabilities at Fair Value on a Recurring Basis	The following table presents on a gross basis our derivative assets and liabilities including both current and noncurrent portions, that are measured at fair value on a recurring basis within the fair value hierarchy, as of June 30, 2016 , September 30, 2015 and June 30, 2015 : Asset (Liability) Level 1 Level 2 Level 3 Total June 30, 2016: Assets: Propane contracts $ — $ 14,063 $ — $ 14,063 Liabilities: Propane contracts $ — $ (9,729 ) $ — $ (9,729 ) September 30, 2015: Assets: Propane contracts $ — $ 1,242 $ — $ 1,242 Liabilities: Propane contracts $ — $ (58,579 ) $ — $ (58,579 ) June 30, 2015: Assets: Propane contracts $ — $ 308 $ — $ 308 Liabilities: Propane contracts $ — $ (58,482 ) $ — $ (58,482 )

Derivative Instruments and He22

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Jun. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Components of Fair Value of Derivative Assets and Liabilities	The following table presents our derivative assets and liabilities, as well as the effects of offsetting, as of June 30, 2016 and 2015 : June 30, June 30, Derivative assets not designated as hedging instruments: Propane contracts $ 14,063 $ 308 Total derivative assets - gross 14,063 308 Gross amounts offset in the balance sheet (4,204 ) (308 ) Total derivative assets - net $ 9,859 $ — Derivative liabilities not designated as hedging instruments: Propane contracts $ (9,729 ) $ (58,482 ) Total derivative liabilities - gross (9,729 ) (58,482 ) Gross amounts offset in the balance sheet 4,204 308 Cash collateral pledged — 2,000 Total derivative liabilities - net $ (5,525 ) $ (56,174 )
Components of Derivative Instruments Gain (Loss) In Statement of Operations	The following tables provide 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, 2016 and 2015 : Gain Location of Gain Three Months Ended June 30, 2016 2015 Cash Flow Hedges: Propane contracts $ — $ 213 Cost of sales - propane Gain (Loss) Location of Gain (Loss) Three Months Ended June 30, 2016 2015 Derivatives Not Designated as Hedging Instruments: Propane contracts $ 20,409 $ (12,216 ) Cost of sales - propane Gain Location of Gain Nine Months Ended June 30, 2016 2015 Cash Flow Hedges: Propane contracts $ — $ 2,518 Cost of sales - propane Gain (Loss) Recognized in Income Location of Gain (Loss) Nine Months Ended June 30, 2016 2015 Derivatives Not Designated as Hedging Instruments: Propane contracts $ 4,579 $ (192,701 ) Cost of sales - propane

Nature of Operations (Details)

Nature of Operations (Details)	9 Months Ended
	Jun. 30, 2016employeestate
General Partners Interest
Number of states in which the company has market share (in states) | state	50
Limited partner interest held by AmeriGas Partners in AmeriGas OLP (as a percent)	98.99%
Employees of the AmeriGas Partners and the Operating Partnership (in employees) | employee	0
AmeriGas Propane Inc Partnership Interest In AmeriGas Partners
General Partners Interest
General partners ownership interest (as a percent)	1.00%
AmeriGas Propane Inc Partnership Interest In AmeriGas OLP
General Partners Interest
General partners ownership interest (as a percent)	1.01%

Summary of Significant Accoun24

Summary of Significant Accounting Policies (Details) - USD ($)	3 Months Ended		9 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Sep. 30, 2015	Sep. 30, 2014
General Partner Interest
Dilutive effect of theoretical distributions of net income on earnings (in usd per unit)	$ 0	$ 0	$ 0.03	$ 0.01
Amounts remaining in AOCI related to commodity derivative instruments	$ 1,205,985,000	$ 1,346,420,000	$ 1,205,985,000	$ 1,346,420,000	$ 1,200,373,000	$ 1,360,890,000
AOCI Related to Commodity Derivative Instruments
General Partner Interest
Amounts remaining in AOCI related to commodity derivative instruments	$ 0		$ 0
AmeriGas Propane Inc Partnership Interest In AmeriGas Partners
General Partner Interest
General partner interest percentage	1.00%		1.00%

Summary of Significant Accoun25

Summary of Significant Accounting Policies - Schedule of Income Per Limited Partner Unit (Details) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Accounting Policies [Abstract]
Net (loss) income attributable to AmeriGas Partners, L.P.	$ (33,069)	$ (25,578)	$ 293,812	$ 260,906
Adjust for general partner share and theoretical distributions of net (loss) income attributable to AmeriGas Partners, L.P. to the general partner in accordance with the two-class method for MLPs	(10,101)	(8,389)	(33,039)	(25,695)
Common Unitholders’ interest in net (loss) income attributable to AmeriGas Partners, L.P. under the two-class method for MLPs	$ (43,170)	$ (33,967)	$ 260,773	$ 235,211
Weighted average Common Units outstanding—basic (thousands) (in units)	92,960	92,918	92,945	92,908
Potentially dilutive Common Units (thousands) (in units)	0	0	74	64
Weighted average Common Units outstanding—diluted (thousands) (in units)	92,960	92,918	93,019	92,972

Goodwill And Intangible Asset26

Goodwill And Intangible Assets - Components of Goodwill and Intangible Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Sep. 30, 2015	Jun. 30, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill (not subject to amortization)	$ 1,978,894	$ 1,956,688	$ 1,954,791
Intangible assets:
Customer relationships and noncompete agreements	529,739	514,333	512,552
Accumulated amortization	(192,210)	(163,564)	(154,147)
Intangible assets, net (definite-lived)	337,529	350,769	358,405
Trademarks and tradenames (indefinite-lived)	82,944	82,944	82,944
Total intangible assets, net	$ 420,473	$ 433,713	$ 441,349

Goodwill and Intangible Asset27

Goodwill and Intangible Assets (Details) - USD ($)	3 Months Ended		9 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Finite-Lived Intangible Assets
Amortization expense of intangible assets	$ 9,545,000	$ 9,473,000	$ 28,646,000	$ 28,487,000
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity
Remainder of Fiscal 2016	9,737,000		9,737,000
Fiscal 2,017	37,148,000		37,148,000
Fiscal 2,018	35,788,000		35,788,000
Fiscal 2,019	34,592,000		34,592,000
Fiscal 2,020	$ 33,410,000		33,410,000
Cost of Sales
Finite-Lived Intangible Assets
Amortization expense of intangible assets			$ 0

Debt (Details)

Debt (Details) - USD ($)	Jun. 27, 2016	Jun. 30, 2016	Sep. 30, 2016	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Debt Instrument [Line Items]
Loss on extinguishments of debt		$ 37,086,000		$ 37,086,000	$ 0	$ 37,086,000	$ 0
Tender premium		29,676,000
Write-off of debt issuance costs		$ 6,748,000
Scenario, Forecast
Debt Instrument [Line Items]
Loss on extinguishments of debt			$ 12,000,000
Senior Notes
Debt Instrument [Line Items]
Principal amount	$ 1,270,001,000
Aggregate principal amount of Tendered Notes redeemed	917,143,000
Senior Notes | 5.625% Senior Notes due May 2024
Debt Instrument [Line Items]
Principal amount	$ 675,000,000
Stated interest rate	5.625%
Senior Notes | 5.875% Senior Notes due August 2026
Debt Instrument [Line Items]
Principal amount	$ 675,000,000
Stated interest rate	5.875%
Senior Notes | 6.50% Senior Notes due May 2021
Debt Instrument [Line Items]
Principal amount	$ 270,001,000
Stated interest rate		6.50%		6.50%		6.50%
Aggregate principal amount of Tendered Notes redeemed	203,476,000
Senior Notes | 6.75% Senior Notes due May 2020
Debt Instrument [Line Items]
Principal amount	550,000,000
Stated interest rate		6.75%		6.75%		6.75%
Aggregate principal amount of Tendered Notes redeemed	406,946,000
Senior Notes | 6.25% Senior Notes due August 2019
Debt Instrument [Line Items]
Principal amount	450,000,000
Stated interest rate		6.25%		6.25%		6.25%
Aggregate principal amount of Tendered Notes redeemed	$ 306,721,000

Debt - Schedule of Long-term De

Debt - Schedule of Long-term Debt Instruments (Details) - USD ($)	Jun. 27, 2016	Jun. 30, 2016	Jun. 30, 2015
Debt Instrument [Line Items]
Remaining Amounts Outstanding at June 30, 2016		$ 2,718,085,000	$ 2,289,590,000
Senior Notes
Debt Instrument [Line Items]
Aggregate Principal Amounts	$ 1,270,001,000
Amounts Repaid on June 27, 2016	917,143,000
Remaining Amounts Outstanding at June 30, 2016		352,858,000
Senior Notes | 6.50% Senior Notes due May 2021
Debt Instrument [Line Items]
Aggregate Principal Amounts	270,001,000
Amounts Repaid on June 27, 2016	203,476,000
Remaining Amounts Outstanding at June 30, 2016		66,525,000
Senior Notes | 6.75% Senior Notes due May 2020
Debt Instrument [Line Items]
Aggregate Principal Amounts	550,000,000
Amounts Repaid on June 27, 2016	406,946,000
Remaining Amounts Outstanding at June 30, 2016		143,054,000
Senior Notes | 6.25% Senior Notes due August 2019
Debt Instrument [Line Items]
Aggregate Principal Amounts	450,000,000
Amounts Repaid on June 27, 2016	$ 306,721,000
Remaining Amounts Outstanding at June 30, 2016		$ 143,279,000

Commitments and Contingencies (

Commitments and Contingencies (Details)	6 Months Ended	9 Months Ended
	Oct. 31, 2014lawsuit	Jun. 30, 2016lb
Commitments and Contingencies Disclosure [Abstract]
Class action lawsuits (more than 35) | lawsuit	35
FTC Cylinder Investigation
Loss Contingencies
Amount of propane in cylinders before reduction (in pounds)		17
Amount of propane in cylinders after reduction (in pounds)		15

Fair Value Measurements - Finan

Fair Value Measurements - Financial Assets and Financial Liabilities at Fair Value On a Recurring Basis (Details) - Fair Value, Measurements, Recurring - Propane Contracts - USD ($) $ in Thousands	Jun. 30, 2016	Sep. 30, 2015	Jun. 30, 2015
Assets:
Derivative Assets	$ 14,063	$ 1,242	$ 308
Liabilities:
Derivative Liabilities	(9,729)	(58,579)	(58,482)
Level 1
Assets:
Derivative Assets	0	0	0
Liabilities:
Derivative Liabilities	0	0	0
Level 2
Assets:
Derivative Assets	14,063	1,242	308
Liabilities:
Derivative Liabilities	(9,729)	(58,579)	(58,482)
Level 3
Assets:
Derivative Assets	0	0	0
Liabilities:
Derivative Liabilities	$ 0	$ 0	$ 0

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Carrying amount of long-term debt	$ 2,718,085	$ 2,289,590
Estimated fair value of long-term debt	$ 2,774,520	$ 2,402,239

Derivative Instruments and He33

Derivative Instruments and Hedging Activities (Details) - gal gal in Millions	9 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Volume of commodity derivative (gallons)	259.4	292.7
Maximum period of price risk cash flow hedging (in months)	39 months

Derivative Instruments and He34

Derivative Instruments and Hedging Activities - Components of Fair Value of Derivative Assets and Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Jun. 30, 2015
Derivative Assets, Fair Value
Derivative assets	$ 14,063	$ 308
Gross amounts offset in the balance sheet	(4,204)	(308)
Total derivative assets - net	9,859	0
Derivative Liabilities, Fair Value
Derivative liabilities	(9,729)	(58,482)
Gross amounts offset in the balance sheet	4,204	308
Cash collateral pledged	0	2,000
Total derivative liabilities - net	(5,525)	(56,174)
Not Designated as Hedging Instrument | Propane Contracts
Derivative Assets, Fair Value
Derivative assets	14,063	308
Derivative Liabilities, Fair Value
Derivative liabilities	$ (9,729)	$ (58,482)

Derivative Instruments and He35

Derivative Instruments and Hedging Activities - Components of Derivative Instruments Gain Loss in Statement of Operations (Details) - Propane Contracts - Cost of Sales - Propane - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Designated as Hedging Instrument | Cash Flow Hedges
Derivative Instruments, Gain (Loss)
Gain Reclassified from AOCI and Noncontrolling Interest into Income	$ 0	$ 213	$ 0	$ 2,518
Not Designated as Hedging Instrument
Derivative Instruments, Gain (Loss)
Gain (Loss) Recognized in Income	$ 20,409	$ (12,216)	$ 4,579	$ (192,701)

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($)	Oct. 13, 2014	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
General Partner | Reimbursed Expenses or Payments
Related Party Transaction
Related party costs and expenses		$ 129,773,000	$ 135,631,000	$ 431,314,000	$ 440,946,000
General Partner | UGI Corp | General and Administrative Services
Related Party Transaction
Related party costs and expenses		4,392,000	5,024,000	13,784,000	18,126,000
General Partner | UGI Corp | Office and Insurance Expenses
Related Party Transaction
Related party costs and expenses		595,000	711,000	1,843,000	2,171,000
Affiliated Entity | Energy Services | Propane Purchases
Related Party Transaction
Related party costs and expenses		0	0	0	0
Affiliated Entity | Affiliates of UGI | Propane Sales
Related Party Transaction
Revenue from related parties		30,000	97,000	335,000	1,190,000
Affiliated Entity | UGI HVAC Enterprises
Related Party Transaction
Purchase price (in cash)	$ 2,000,000
Shared service agreement (SSA) expenses		$ 256,000	$ 256,000	$ 768,000	$ 734,000